short-term energy outlook

U.S. Energy Information Administration | Short-Term Energy Outlook September 2021 1 Note: EIA completed modeling and analysis for this report on Thursday September 2, 2021

September 2021

Short-Term Energy Outlook

Forecast highlights

Global liquid fuels

• The September Short-Term Energy Outlook (STEO) remains subject to heightened levels of uncertainty related to the ongoing recovery from the COVID-19 pandemic. U.S. economic activity continues to rise after reaching multiyear lows in the second quarter of 2020 (2Q20). U.S. gross domestic product (GDP) declined by 3.4% in 2020 from 2019 levels. This STEO assumes U.S. GDP will grow by 6.0% in 2021 and by 4.4% in 2022. The U.S. macroeconomic assumptions in this outlook are based on forecasts by IHS Markit. Our forecast assumes continuing economic growth and increasing mobility. Any developments that would cause deviations from these assumptions would likely cause energy consumption and prices to deviate from our forecast.

• Brent crude oil spot prices averaged $71 per barrel (b) in August, down $4/b from July but up $26/b from August 2020. Brent prices have risen over the past year as result of steady draws on global oil inventories, which averaged 1.8 million barrels per day (b/d) during the first half of 2021 (1H21). We expect Brent prices will remain near current levels for the remainder of 2021, averaging $71/b during the fourth quarter of 2021 (4Q21). In 2022, we expect that growth in production from OPEC+, U.S. tight oil, and other non-OPEC countries will outpace slowing growth in global oil consumption and contribute to Brent prices declining to an annual average of $66/b.

• More than 90% of crude oil production in the Federal Offshore Gulf of Mexico (GOM) was offline in late August following Hurricane Ida. As a result of the outage, GOM production averaged 1.5 million b/d in August, down 0.3 million b/d from July. We expect that crude oil production in the GOM will gradually come back online during September and average 1.2 million b/d for the month before returning to an average of 1.7 million b/d in 4Q21.

• Total U.S. crude oil production averaged 11.3 million b/d in June—the most recent monthly historical data point. We forecast it will remain near that level through the end of 2021 before increasing to an average of 11.7 million b/d in 2022, driven by growth in onshore tight oil production. We expect growth will result from operators beginning to increase rig additions, offsetting production decline rates.

https://www.eia.gov/petroleum/production/

U.S. Energy Information Administration | Short-Term Energy Outlook September 2021 2

• We estimate that 98.4 million b/d of petroleum and liquid fuels was consumed globally in August, an increase of 5.7 million b/d from August 2020 but still 4.0 million b/d less than in August 2019. We forecast that global consumption of petroleum and liquid fuels will average 97.4 million b/d for all of 2021, which is a 5.0 million b/d increase from 2020, and by an additional 3.6 million b/d in 2022 to average 101.0 million b/d, almost even with 2019 levels.

• U.S. regular gasoline retail prices averaged $3.16 per gallon (gal) in August, the highest monthly average price since October 2014. Recent gasoline price increases reflect rising wholesale gasoline margins amid relatively low gasoline inventories. In addition, recent impacts from Hurricane Ida on several U.S. Gulf Coast refineries are adding upward price pressures in the near term. Estimated gasoline margins surpassed 70 cents/gal in late August. We expect margins will remain elevated in the coming weeks as refining operations as U.S. Gulf Coast remain disrupted. We forecast that retail gasoline prices will average $3.14/gal in September before falling to $2.91/gal, on average, in 4Q21. The expected drop in retail gasoline prices reflects our forecast that gasoline margins will decline from currently elevated levels, both as a result of rising refinery runs as operations return in the first half of September following Hurricane Ida and because of typical seasonality.

• Propane net exports in our forecast average close to 1.2 million b/d for the remainder of 2021, reflecting elevated global demand for U.S. propane and reduced supply from other sources related to ongoing OPEC+ production cuts. In 1H22, we assume global production of propane and butanes will rise as OPEC+ countries increase crude oil production. We expect this increase will limit additional demand for U.S. propane exports, despite growing global propane demand, and keep U.S. net propane exports close to 1.2 million b/d in 2022.

Natural Gas

• In August, the natural gas spot price at Henry Hub averaged $4.07 per million British thermal units (MMBtu), which is up from the July average of $3.84/MMBtu. The August increase reflects hotter temperatures in August on average across the United States compared with July, which caused demand for natural gas in the electric power sector to be higher than expected. Prices rose further in late August when Hurricane Ida caused a decline in natural gas production in the GOM.

• Henry Hub spot prices in August were $1.77/MMBtu higher than in August 2020. Steadily rising natural gas prices over the past year primarily reflects: growth in liquefied natural gas (LNG) exports, rising domestic natural gas consumption for sectors other than electric power, and relatively flat natural gas production. We expect the Henry Hub spot price will average $4.00/MMBtu in 4Q21, as the factors that drove prices higher during August lessen. Forecast Henry Hub prices this winter reach a monthly average

https://www.eia.gov/todayinenergy/detail.php?id=49416


https://www.eia.gov/energyexplained/gasoline/price-fluctuations.php#:%7E:text=Seasonal%20demand%20and%20specifications%20for,and%20formulations%20also%20change%20seasonally.


peak of $4.25/MMBtu in January and generally decline through 2022, averaging $3.47/MMBtu for the year amid rising U.S. natural gas production and slowing growth in LNG exports.

• More than 90% of natural gas production in the GOM was offline in late August following Hurricane Ida. GOM production of marketed natural gas averaged 1.9 billion cubic feet per day (Bcf/d) in August, down 0.4 Bcf/d from July. We expect that natural gas production in the GOM will gradually come back online during the first half of September and average 1.5 Bcf/d for the month before returning to an average of 2.1 Bcf/d in 4Q21.

• We expect dry natural gas production will average 92.7 Bcf/d in the United States during 2H21—up from 91.7 Bcf/d in 1H21—and then rise to 95.4 Bcf/d in 2022, driven by natural gas and crude oil prices, which we expect to remain at levels that will support enough drilling to sustain production growth.

• We expect that U.S. consumption of natural gas will average 82.5 (Bcf/d) in 2021, down 0.9% from 2020. U.S. natural gas consumption declines in 2021, in part, because electric power generators switch to coal from natural gas as a result of higher natural gas prices. In 2021, we expect residential and commercial natural gas consumption combined will rise by 1.2 Bcf/d from 2020 and industrial consumption will rise by 0.6 Bcf/d from 2020. Rising natural gas consumption in sectors other than the electric power sector results from expanding economic activity and colder winter temperatures in 2021 compared with 2020. We expect U.S. natural gas consumption will average 82.6 Bcf/d in 2022, mostly unchanged from 2021.

• We estimate that U.S. natural gas inventories ended August 2021 at about 2.9 trillion cubic feet (Tcf), which is 7% lower than the five-year (2016–20) average for this time of year. Injections into storage this summer have been below the previous five-year average, largely as a result of hot weather and high exports occurring amid relatively flat natural gas production. We forecast that inventories will end the 2021 injection season (end of October) at almost 3.6 Tcf, which would be 5% below the five-year average.

Electricity, coal, renewables, and emissions

• We expect the share of electricity generation produced by natural gas in the United States will average 35% in 2021 and 34% in 2022, down from 39% in 2020. In 2021, the forecast share for natural gas as a generation fuel declines in response to our expectation of a higher delivered natural gas price for electricity generators, which we forecast will average $4.69/MMBtu in 2021 compared with $2.39/MMBtu in 2020. The share of natural gas as a generation fuel also declines through 2022 because of expected increases in generation from renewable sources. As a result of the higher expected natural gas prices, the forecast share of electricity generation from coal rises from 20%




in 2020 to about 24% in both 2021 and 2022. New additions of solar and wind generating capacity are offset somewhat by reduced generation from hydropower this year, resulting in the forecast share of all renewables in U.S. electricity generation to average 20% in 2021, about the same as last year, before rising to 22% in 2022. The nuclear share of U.S. electricity generation declines from 21% in 2020 to 20% in 2021 and to 19% in 2022 as a result of retiring capacity at some nuclear power plants.

• We forecast that planned additions to U.S. wind and solar generating capacity in 2021 and 2022 will increase electricity generation from those sources. We estimate that the U.S. electric power sector added 14.7 gigawatts (GW) of new wind capacity in 2020. We expect 17.6 GW of new wind capacity will come online in 2021 and 6.3 GW in 2022. Utility-scale solar capacity rose by an estimated 10.5 GW in 2020. Our forecast for added utility-scale solar capacity is 15.9 GW for 2021 and 16.3 GW for 2022. We expect significant solar capacity additions in Texas during the forecast period. In addition, we project that after increasing by 4.5 GW in 2020, small-scale solar capacity (systems less than 1 megawatt) will grow 5.8 GW and 5.7 GW in 2021 and 2022 respectively.

• Coal production in our forecast totals 601 million short tons (MMst) in 2021, 66 MMst more than in 2020. We expect demand for coal from the electric power sector to increase by 100 MMst in 2021 as a result of high natural gas prices, and coal exports to increase by 21 MMSt. However, production is unlikely to match those increases in demand in the near term due to capacity constraints at coal mines and limited available transportation. In 2022, we expect coal production to increase by 47 MMst to 648 MMst, despite our forecast of declines in coal consumption, as the production and transportation constraints experienced in 2021 ease. Secondary inventories of coal at electric utilities decreased in 1H21, and we forecast this trend will continue into 2H21 and 2022.

• We estimate that U.S. energy-related carbon dioxide (CO2) emissions decreased by 11% in 2020 as a result of less energy consumption related to reduced economic activity and responses to COVID-19. For 2021, we forecast energy-related CO2 emissions will increase about 8% from the 2020 level as economic activity increases and leads to rising energy use. We also expect energy-related CO2 emissions to rise in 2022 but at a slower rate of 2%. We forecast that after declining by 19% in 2020, coal-related CO2 emissions will rise by 22% in 2021 and then decrease by 2% in 2022. Short-term changes in energy-related CO2 can be affected by temperature. A recent STEO supplement examines these dynamics.






https://www.eia.gov/outlooks/steo/special/supplements/2021/2021_sp_02.pdf


Petroleum and natural gas markets review

Crude oil

Prices: The front-month futures price for Brent crude oil settled at $73.03 per barrel (b) on September 2, 2021, up 14 cents/b from $72.89/b on August 2. The front-month futures price for West Texas Intermediate (WTI) crude oil for delivery at Cushing, Oklahoma, decreased by $1.27/b during the same period, settling at $69.99/b on September 2 (Figure 1).

Brent and WTI prices both decreased in the first half of August. Increasing OPEC+ crude oil production and flattening global petroleum demand in response to rising COVID-19 cases contributed to the falling crude oil prices. Both benchmarks reached their low points of the month on August 20: Brent at $65/b and WTI at $62/b. Crude oil prices increased in the latter part of the month, and Brent prices are just above where they started August. On a monthly average basis, the Brent spot price in August decreased $4/b compared with July. Although crude oil prices have been gradually increasing in the wake of the initial COVID-19-induced price decrease, August marks the fourth month since May 2020 in which the price has declined. This price decrease may reflect market concerns about the demand impacts of a possibly continuing COVID-19 pandemic and spread of the Delta variant.

In the September STEO, our outlook for global oil markets is largely unchanged from last month, and we continue to expect Brent prices will average $71/b in the fourth quarter of 2021 (4Q21) and $66/b in 2022. One notable change is that we have revised global oil demand expectations down in 2021, accounting for reactions to the proliferation of the Delta variant. We decreased our oil demand expectations primarily in the middle months of 2021, and we reduced forecast global oil demand by an average of 0.5 million b/d in the 3Q21. We now expect global oil


demand to grow by 5.0 million b/d in 2021, down from expected growth of 5.3 million b/d in last month’s forecast.

In the near term, the impact of Hurricane Ida on U.S. offshore production, reported incidents at Mexican offshore facilities, and lower-than-expected production in several non-OPEC countries have contributed to lower crude oil production offsetting some of the price effects of lower-than-expected oil demand. How the market will continue to process news about further COVID-19 outbreaks, even in countries with rising numbers of vaccinated people, remains an important uncertainty in our forecast. The production decisions of OPEC+ given an evolving demand outlook will also be a key driver of oil price formation in the coming months. Our forecast assumes that OPEC+ will generally produce at a level that achieves a relatively balanced oil market.

Brent front-month price and copper-to-gold front-month price ratio: Lower crude oil prices in August reflect flattening global petroleum demand, likely driven by responses to rising COVID-19 cases and the spread of the Delta variant. The decline in global commodity prices was not limited to crude oil, however. The copper-to-gold ratio is a measure of the value of copper relative to the value of gold. Copper is a metal whose value increases during periods of growing industrial production and economic activity. Gold is a metal whose value can increase during periods of economic uncertainty or changes in inflation expectations. On August 19, the copper-to-gold ratio (indexed to October 1, 2020, the start of 4Q20) decreased to its lowest level since February 2021 (Figure 2). After rising mostly in tandem with crude oil prices through May 2021, the ratio weakened slightly over the summer, while crude oil prices continued rising through July. The weaker copper-to-gold ratio reflects lower global copper prices over the summer which declined primarily because of responses to rising COVID-19 cases globally. Unlike the copper-to-gold ratio, global crude oil prices were particularly elevated through the summer, reflecting sector-specific impacts on the global crude oil price that are unrelated to other commodities, such as the sustained OPEC+ crude oil production curtailment. However, the recent decreases in crude oil prices have brought its relative change compared to the beginning 4Q20 closer to the change in the copper-to-gold ratio, illustrating the role of macroeconomic demand factors in global commodities markets and the easing of the role of supply side factors that had supported crude oil prices earlier in the summer. Since the August 19 low point for both crude oil and the copper-to-gold ratio, positive reports of reduced COVID-19 cases in China and some other Asian countries have contributed to stronger expectations for global commodities demand, affecting both copper and oil prices.

https://www.bsee.gov/newsroom/latest-news/statements-and-releases/press-releases/bsee-monitors-gulf-of-mexico-oil-and-47

https://www.reuters.com/business/energy/exclusive-offshore-platform-fire-cuts-mexico-oil-output-by-444000-bpd-document-2021-08-23/


Crude oil front-month to third-month futures price spread: On August 16, the five-day moving average spread between the front-month and third-month futures price for Brent crude oil fell to its lowest level since May 31, 2021 (Figure 3). Although concerns over rising COVID-19 cases introduced downward price pressure and increased volatility into the market in August, the sustained backwardation (when near-term prices are higher than longer-dated ones) in the 1-3 futures spreads indicate that the global petroleum complex is still relying on petroleum inventories to meet demand. High backwardation typically indicates market participants are selling crude oil from storage, resulting in stock draws. The spread for Brent averaged $1.25/b in June and $1.51/b in July, and rarely narrowed below $1.30/b from mid-June through July. Global oil stocks draws from January through July averaged 1.7 million b/d, bolstered by draws of 2.7 million b/d in June. In August, the Brent 1-3 spread narrowed to less than than 90 cents/b. Although the spread remained positive, the decrease likely reflected lower front-month crude oil prices due to temporarily lower demand expectations. We estimate net global stock draws in August were 1.6 million b/d, and we expect them to continue at 1.3 million b/d in September. In line with sustained inventory withdrawals, the Brent 1-3 spread widened back above $1.00/b on August 25 and was $1.56/b as of September 2. The WTI spread experienced a similarly rapid decline in mid-August, reaching its recent low of $0.55/b on August 12, but unlike Brent, it has not increased as much later in the month and has remained below $1.00/b as of September 2.

https://www.cmegroup.com/education/courses/introduction-to-ferrous-metals/what-is-contango-and-backwardation.html



Producer/merchant open interest in WTI futures: Open interest in WTI futures by producers and merchants shifted to a net long position as of the August 24 Commitment of Traders report from the Commodity Futures Trading Commission (CFTC), and overall open interest from producers and merchants has decreased (Figure 4). The lower open interest reflects both an overall reduction in oil commodity futures trading by producers and merchants and a reduction in short positions. Producers and merchants is a CFTC category that include crude oil producers and refiners. These market participants often use futures as a means of financially hedging against crude oil price changes. The net producer/merchant position is often short.

Reduced producer/merchant open interest may reflect an effort by certain upstream producers to reduce their hedged positions because of higher overall crude prices after experiencing particularly high financial losses on hedged crude oil production compared to unhedged barrels


in 1H21. Hedged crude oil can often account for relative losses compared to unhedged production when crude oil prices increase, because producers typically deploy hedges to mitigate downside price risks, but hedged barrels of crude oil do not benefit from any price increases. Because of relatively rapid price increases in 1H21, any barrels that producers hedged at a lower price point resulted in foregoing the benefits of crude oil’s rapid price increases during that period.

Some upstream producers such as Devon Energy, Diamondback, and Ovintiv reported losses in their second-quarter financial filings because of hedging at around $50/b. With WTI crude oil spot prices averaging $66/b for the quarter, these companies reported losses on their hedged barrels, usually of around $13/b compared with un-hedged barrels. We previously discussed the decreasing volume of net long positions by money managers in the August STEO, and the decreasing availability of market participants with long positions corresponds with decreased volume of producer/merchant short positions, which had been above 600,000 contracts on a monthly average basis since January 2021, but have since decreased to about 415,000 contracts as of the August 24 report. Producer/merchant open interest in long positions has also decreased compared with earlier in the year, but the overall reduction in long contract volume has been relatively less, contributing to the shift in the net long contract volume to 25,000 contracts. The August 24 report also showed combined producer/merchant open interest had decreased to 856,000 contracts, its lowest volume so far in 2021.

Petroleum products

Gasoline prices: The front-month futures price of RBOB (the petroleum component of gasoline used in many parts of the country) settled at $2.16 per gallon (gal) on September 2, down 11 cents/gal from August 2 (Figure 5). The RBOB–Brent crack spread (the difference between the price of RBOB and the price of Brent crude oil) decreased by 11 cents/gal to settle at 42 cents/gal during the same period. The RBOB–Brent crack spread declined by 14 cents/gal on September 1 when the front-month RBOB contract rolled over to October delivery, which reflects winter grade gasoline that is cheaper for refineries to produce. In August, however, the RBOB–Brent crack spread averaged 55 cents/gal, the highest monthly average crack spread since July 2015.

https://d18rn0p25nwr6d.cloudfront.net/CIK-0001090012/6b3839e0-732a-4f41-aef9-5017a298b455.pdf

https://www.diamondbackenergy.com/node/13591/html

https://app.quotemedia.com/data/downloadFiling?webmasterId=101533&ref=116023998&type=PDF&formType=10-Q&dateFiled=2021-07-29&cik=0001792580&CK=1792580&symbol=0001792580&companyName=Ovintiv

https://www.eia.gov/outlooks/steo/archives/Aug21.pdf#page=8


August’s high RBOB–Brent crack spread was likely a result of high summer driving demand, low gasoline stocks, refinery disruptions from Hurricane Ida, and relatively high ethanol costs. We estimate U.S. gasoline consumption averaged 9.4 million barrels per day (b/d) in August, which is 0.9 million b/d (10%) higher than in August 2020 but 0.4 million b/d (4%) lower than the August 2019 level. Several months of relatively high gasoline consumption during the summer driving months have combined with low gasoline production to contribute to low gasoline stocks. We estimate gasoline stocks ended August at 225.6 million barrels, the lowest end-of-August level since 2015. Furthermore, refinery disruptions from Hurricane Ida likely supported increased crack spreads at the end of August. The RBOB–Brent crack spread, which was 49 cents/gal on August 24, increased on August 25 and remained around 55 cents/gal through the end of the month. At least nine refineries in Louisiana reduced or shut in operations prior to Hurricane Ida, and we forecast refinery operations in the U.S. Gulf Coast will gradually restart operation over the first half of September. Because of the refinery disruptions, we expect monthly average refinery runs will be about 700,000 b/d lower in September than they would be without the disruptions. Lower refinery runs will likely contribute to continuing declines in gasoline stocks during September and support gasoline crack spreads in the coming weeks.

Recently, record-high prices for renewable identification number (RIN) credits have been another contributing factor to higher-than-average RBOB prices. RINs are the compliance mechanisms used for the Renewable Fuel Standard (RFS) program, which the U.S. Environmental Protection Agency (EPA) administers. For most of the history of RFS, RIN prices have typically been at a level that only minimally affected RBOB prices. In late 2020 and 2021, however, RIN prices have been high in large part because of high biofuel feedstock costs. The higher cost of RFS compliance for gasoline producers and importers as a result of higher RIN prices may pass through to affect RBOB prices. Although RIN prices have decreased from their record highs in August, they still remain high relative to their average levels prior to 2021 and are likely still adding upward pressure to RBOB prices.

https://www.energy.gov/sites/default/files/2021-08/TLP-WHITE_DOE%20Situation%20Update_Hurricane%20Ida_2.pdf

https://www.eia.gov/petroleum/weekly/archive/2021/210218/includes/analysis_print.php



Fuel ethanol and corn prices: Corn and ethanol prices have decreased slightly since corn prices peaked at $7.73 per bushel on May 7 and ethanol prices peaked at $2.48/gal in late June. The front-month futures price of corn closed at $5.16 per bushel on September 2, an increase of $1.67 per bushel from September 2, 2020, but $2.57 per bushel lower than the peak price on May 7. The front-month futures price of fuel ethanol settled at $2.22/gal on September 2, 2021, an increase of 86 cents/gal from September 2, 2020, and 6 cents/gal higher than the front-month RBOB contract. The fuel ethanol–corn crush spread (the difference between the price of fuel ethanol and the price of its corn inputs) has been positive since mid-July after a few atypical months of negative spreads (Figure 6).

The decrease in fuel ethanol prices is mostly the result of lower prices for corn, which is the feedstock for fuel ethanol. Corn prices increased in the first half of 2021 because of high demand in China, concerns of low production as a result of cold weather in the Midwest, and a La Niña weather pattern that brought hot and dry weather, which is not ideal for corn production, to major exporters Brazil and Argentina. Corn prices have come down since June because of increased planted acreage of corn and increased production forecasts in the United States as well as uncertain demand in Asia.

Ethanol prices have decreased by less than corn prices because ethanol is primarily used for gasoline blending and therefore ethanol prices are also tied to gasoline demand, which has been relatively high. In addition, the uncertainty concerning RVO levels for 2021 has supported high RIN demand and ethanol prices. The fact that RBOB prices generally increased in July and August, despite lower ethanol prices and lower RIN prices in late August, suggests that gasoline inventory draws in August likely contributed to the crack spread increases seen in the second half of August.

https://www.eia.gov/outlooks/steo/archives/May21.pdf

https://www.globaltimes.cn/page/202106/1226523.shtml

https://www.globaltimes.cn/page/202106/1226523.shtml

https://oceanservice.noaa.gov/facts/ninonina.html

https://www.fas.usda.gov/corn-2019-export-highlights

https://www.nass.usda.gov/Newsroom/2021/06-30-2021.php

https://www.ers.usda.gov/webdocs/outlooks/101632/fds-21g.pdf?v=3542.9

https://www.farmprogress.com/commentary/uncertainty-ahead-corn-exports

https://www.eia.gov/outlooks/steo/archives/aug21.pdf#page=10

https://www.eia.gov/outlooks/steo/archives/aug21.pdf#page=10


Ultra-low sulfur diesel prices: The front-month futures price for ultra-low sulfur diesel (ULSD) for delivery in New York Harbor settled at $2.17/gal on September 2, up 3 cents/gal from August 2 (Figure 7). The ULSD–Brent crack spread (the difference between the price of ULSD and the price of Brent crude oil) increased 3 cents/gal during the same period, settling at 43 cents/gal.

The average ULSD–Brent crack spread increased 3 cents/gal from July to 39 cents/gal in August as a result of higher distillate demand and low production. We estimate that distillate consumption increased by 0.3 million b/d (8%) from July to 4.10 million b/d in August. High freight demand expectations and record congestion at Southern Californian ports suggest that trucking and rail demand will remain high in the upcoming months before winter heating demand provides an additional increase in distillate demand. We forecast distillate demand to exceed 4 million b/d from October 2021 through June 2022.

We also estimate that distillate production in August fell to its lowest level for that month since 2012. Although a reduction in net exports of distillate partly offset the high distillate demand and low distillate production, distillate stocks decreased in August, a month in which distillate stocks typically build.

We expect distillate stocks to continue to decrease through November. The forecast decrease partly reflects Hurricane Ida’s refinery disruptions on the U.S. Gulf Coast and partly reflects our expectations of high distillate demand during the crop harvesting season. Low inventories and expectations of inventory draws through November are likely supporting current above-average distillate crack spreads.

Natural Gas

Prices: The front-month natural gas futures contract for delivery at the Henry Hub settled at $4.64 per million British thermal units (MMBtu) on September 2, 2021, which was up 71

https://talkbusiness.net/2021/08/truck-capacity-remains-tight-freight-demand-still-rolling/

https://talkbusiness.net/2021/08/truck-capacity-remains-tight-freight-demand-still-rolling/

https://www.businessinsider.com/shipping-delays-china-supply-chain-record-ships-stuck-california-ports-2021-8


cents/MMBtu from August 2, 2021 (Figure 9). The average price for front-month natural gas futures contracts in August was $4.03/MMBtu. August was warmer than normal, with 355 cooling degree days (CDD), 8.6% more than the 2011–2020 average. The United States this summer (June—August) had 3.9% more CDDs than the 2011–20 average. The hot weather this summer combined with record exports of liquefied natural gas (LNG) has contributed to month-on-month increases in the Henry Hub futures price since March 2021, leading to the highest August average since 2010. Further upward price pressures came from the arrival of Hurricane Ida, which resulted in more than 90% of offshore natural gas production in the Federal Offshore Gulf of Mexico being shut in during late August.

The Henry Hub front-month futures price increased by 47 cents/MMBtu from $3.90/MMBtu on August 25 to $4.37/MMBtu on August 27, as Hurricane Ida approached the U.S. Gulf Coast, leading producers to evacuate personnel from offshore platforms and to shut in production. On August 27, the U.S. Bureau of Safety and Environmental Enforcement (BSEE) began posting daily Gulf of Mexico hurricane impact updates, indicating that from August 27 to August 31, 9.3 billion cubic feet (Bcf), or 1.9 Bcf/d, of natural gas production was shut in. As of September 2, 91.3% of GOM natural gas production remained shut in. Since the arrival of Hurricane Ida, natural gas prices have remained elevated, and they ended August at $4.38/MMBtu.

Futures price spreads: The natural gas 1st–13th trading month price spread averaged 74 cents/MMBtu in July, the most backwardation (where near-term contract prices are higher than longer-dated ones) since December 2018 (Figure 10). In August, the natural gas 1st–13th month price spread averaged 70 cents/MMBtu. Typically, the 1st–13th price spread will increase when natural gas inventories decrease and will decrease when natural gas inventories increase. The August natural gas inventory level was 578 Bcf below last year’s August level, its largest year-on-year deficit since November 2018, and 222 Bcf below the 2016–2020 average.






Above-average withdrawals of U.S. natural gas from storage during the 2020–2021 winter heating season and below-average injections into storage this summer contributed to our forecast of below-average inventories of natural gas. Relatively flat dry natural gas production and high natural gas exports also contributed to the forecast low inventories. U.S. dry natural gas production and U.S. exports of natural gas (by pipeline and as LNG) were relatively flat from July to August. We expect storage to begin the winter heating season (November 1) at 3,570 Bcf, 182 Bcf below the 2016–2020 average and 359 Bcf below the 2020 level, when natural gas inventories were at near-record highs.

Production: U.S. dry natural gas production has been almost flat this year after its brief decline in February because of severely cold weather in Texas, and we expect production to remain relatively flat for the rest of 2021 (Figure 11). Although production has been increasing, the increase has been relatively small. We expect U.S. dry natural gas production in 2021 to average 92.2 Bcf/d, a 0.8 Bcf/d increase from 2020, compared with an annual average increase of 3.3 Bcf/d from 2011 through 2020. In our forecast, production increases accelerate in 2022, driven by the increase in Henry Hub prices this year. In 2022, we expect production to average 95.4 Bcf/d, an increase of 3.2 Bcf/d from 2021. The increase in production from 2021 to 2022 will put some downward pressure on the Henry Hub price, which we expect to average $3.47/MMBtu next year, a decrease of 16 cents/MMBtu from the average forecast price for 2021.








Notable forecast changes

• In the September STEO, we revised our global liquid fuels consumption forecast down by 0.2 million barrels per day in both 2021 and 2022. The decreased consumption reflects a lower GDP forecast as well as expectations of lower consumption because of travel and other restrictions in response to increases in COVID-19 cases.

• We forecast OPEC crude oil production will average 26.4 million b/d in 2021, down 0.1 million b/d from the August STEO, reflecting our expectation that Iran’s crude oil production will be lower in the second half of 2021 (2H21) than we previously expected. We expect OPEC to produce 28.3 million b/d in 2022, down 0.3 million b/d compared with the August STEO. The downward revision to supply growth is driven by lower global oil demand growth, and we expect some producers to continue to restrain output to maintain relatively balanced oil markets in 2022.

• We forecast Henry Hub spot prices will average $4.00 per million British thermal unit (MMBtu) in 2H21, an increase of 41 cents/MMBtu from last month’s STEO. Forecast prices average $3.47/MMBtu in 2022, an increase of 39 cents from last month’s STEO. The increase largely reflects a higher starting point for our price forecast.

• We forecast U.S. coal production to total 648 million short tons (MMst) in 2022, up 47 MMst (8%) from last month’s STEO. Higher U.S. coal production in this forecast is the result of a 54 MMst increase in our forecast for electric power sector demand for coal in 2022.

This report was prepared by the U.S. Energy Information Administration (EIA), the statistical and analytical agency within the U.S. Department of Energy. By law, EIA's data, analyses, and forecasts are independent of approval by any other officer or employee of the U.S. Government. The views in this report therefore should not be construed as representing those of the U.S. Department of Energy or other federal agencies.

www.eia.govU.S. Energy Information Administration Independent Statistics & Analysis

Short-Term Energy Outlook Chart Gallery

September 8, 2021

0

20

40

60

80

100

120

2016 2017 2018 2019 2020 2021 2022

Sources: U.S. Energy Information Administration, Short-Term Energy Outlook, September 2021, CME Group, Bloomberg, L.P., and Refinitiv an LSEG Business

Note: Confidence interval derived from options market information for the five trading days ending Sep 2, 2021. Intervals not calculated for months with sparse trading in near-the-money options contracts.

West Texas Intermediate (WTI) crude oil price and NYMEX confidence intervalsdollars per barrel

West TexasIntermediate (WTI) spot price

West Texas Intermediate (WTI) crude oil price and NYMEX confidence intervalsdollars per barrel

95% NYMEX futures priceconfidenceintervalupper bound

STEO forecastNYMEX futures price

95% NYMEX futures priceconfidenceinterval

-0.12

-0.42

0.73

-0.16

-1.00

-0.75

-0.50

-0.25

0.00

0.25

0.50

0.75

1.00

1.25

2019 2020 2021 2022

Components of annual gasoline price changesdollars per gallon

Brent crude oil pricewholesale marginover crude

retail marginover wholesale

net change

forecast

0.00

0.50

1.00

1.50

2.00

2.50

3.00

3.50

4.00

4.50

2018 2019 2020 2021 2022

monthly retail regular gasolineannual average gasolinemonthly Brent crude oilannual average Brent

U.S. gasoline and crude oil prices

dollars per gallon

forecast

Source: U.S. Energy Information Administration, Short-Term Energy Outlook, September 2021, and Refinitiv an LSEG Business

-0.12

-0.42

0.73

-0.16

-1.00

-0.75

-0.50

-0.25

0.00

0.25

0.50

0.75

1.00

1.25

2019 2020 2021 2022

Components of annual gasoline price changesdollars per gallon


retail marginover wholesale

net change

forecast

0.00

0.50

1.00

1.50

2.00

2.50

3.00

3.50

4.00

4.50

2018 2019 2020 2021 2022

monthly retail regular gasolineannual average gasolinemonthly Brent crude oilannual average Brent

U.S. gasoline and crude oil prices

dollars per gallon

forecast


-0.13

-0.50

0.62

-0.09

-1.00

-0.75

-0.50

-0.25

0.00

0.25

0.50

0.75

1.00

1.25

2019 2020 2021 2022

Components of annual dieselprices changesdollars per gallon


retail margin over wholesale

forecast

0.00

0.50

1.00

1.50

2.00

2.50

3.00

3.50

4.00

4.50

2018 2019 2020 2021 2022

monthly retail dieselannual average dieselmonthly Brent crude oilBrent annual average

U.S. diesel and crude oil prices

dollars per gallon

forecast


-0.13

-0.50

0.62

-0.09

-1.00

-0.75

-0.50

-0.25

0.00

0.25

0.50

0.75

1.00

1.25

2019 2020 2021 2022

Components of annual dieselprices changesdollars per gallon


retail margin over wholesale

forecast

0.00

0.50

1.00

1.50

2.00

2.50

3.00

3.50

4.00

4.50

2018 2019 2020 2021 2022

monthly retail dieselannual average dieselmonthly Brent crude oilBrent annual average

U.S. diesel and crude oil prices

dollars per gallon

forecast


0

2

4

6

8

10

12

2016 2017 2018 2019 2020 2021 2022

Henry Hub natural gas price and NYMEX confidence intervalsdollars per million Btu

Sources: U.S. Energy Information Administration, Short-Term Energy Outlook, September 2021, CME Group, and Refinitiv an LSEG Business

Note: Confidence interval derived from options market information for the five trading days ending Sep 2, 2021. Intervals not calculated for months with sparse trading in near-the-money options contracts.

95% NYMEX futures priceconfidence intervalupper bound

STEO forecastNYMEX futures price

95% NYMEX futures priceconfidence intervallower bound

Henry Hub spot price

02468

101214161820

2017 2018 2019 2020 2021 2022

monthly residential priceannual average residentialmonthly Henry Hub spot priceHenry Hub annual average

U.S. natural gas pricesdollars per thousand cubic feet

forecast

Sources: U.S. Energy Information Administration, Short-Term Energy Outlook, September 2021, and Refinitiv an LSEG Business

forecast

75

80

85

90

95

100

105

Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4

2016 2017 2018 2019 2020 2021 2022

World liquid fuels production and consumption balancemillion barrels per day

world production

world consumption

//0

-4-202468

Source: U.S. Energy Information Administration, Short-Term Energy Outlook, September 2021

implied stock build

implied stock draw

forecast

75

80

85

90

95

100

105


2016 2017 2018 2019 2020 2021 2022

World liquid fuels production and consumption balancemillion barrels per day

world production

world consumption

//0

-4-202468


implied stock build

implied stock draw

0

1

2

3

4

5

6

Jan 2019 Jan 2020 Jan 2021

Estimated unplanned liquid fuels production outages among OPEC and non-OPEC producers million barrels per day


non-OPECotherUnited StatesCanada

OPECVenezuelaSaudi ArabiaIranKuwaitIraqNigeriaLibya

1.1

-8.7

5.03.6

-10

-8

-6

-4

-2

0

2

4

6

8

10

2019 2020 2021 2022

Components of annual changemillion barrels per day

world changeOrganization of Economic

Cooperation andDevelopment (OECD)

non-OECD

forecast

65

70

75

80

85

90

95

100

105

2019 2020 2021 2022

monthly historymonthly forecastannual average

World liquid fuels consumption million barrels per day

//0


1.1

-8.7

5.03.6

-10

-8

-6

-4

-2

0

2

4

6

8

10

2019 2020 2021 2022


world changeOrganization of Economic

Cooperation andDevelopment (OECD)

non-OECD

forecast

65

70

75

80

85

90

95

100

105

2019 2020 2021 2022



//0


1.1

-8.7

5.03.6

-10

-8

-6

-4

-2

0

2

4

6

2019 2020 2021 2022

Annual change in world liquid fuels consumption million barrels per day


forecast

worldother non-OECDMiddle EastIndiaChinaother OECDUnited States

-0.1

-6.5

2.0

5.3

-8

-6

-4

-2

0

2

4

6

8

2019 2020 2021 2022

Components of annual change million barrels per day

forecastOPEC countriesnon-OPEC

EurasiaNorth AmericaLatin Americaother non-OPEC

net change

80

85

90

95

100

105

2019 2020 2021 2022

monthly history

monthly forecast

annual average

World crude oil and liquid fuels production million barrels per day

//


-0.1

-6.5

2.0

5.3

-8

-6

-4

-2

0

2

4

6

8

2019 2020 2021 2022

Components of annual change million barrels per day

forecastOPEC countriesnon-OPEC

EurasiaNorth AmericaLatin Americaother non-OPEC

net change

80

85

90

95

100

105

2019 2020 2021 2022

monthly history

monthly forecast

annual average

World crude oil and liquid fuels production million barrels per day

//

0


2

0

20

40

60

80

100

120

2019 2020 2021 2022


non-OECD

Organization for Economic Cooperation

forecast

0

20

40

60

80

100

120

2019 2020 2021 2022

World liquid fuels production million barrels per day

non-OPEC

Organization of the Petroleum Exporting

forecast


forecast

0

20

40

60

80

100

120

2019 2020 2021 2022


non-OECD

Organization for Economic Cooperationand Development (OECD)

forecast

0

20

40

60

80

100

120

2019 2020 2021 2022

World liquid fuels production million barrels per day

non-OPEC

Organization of the Petroleum ExportingCountries (OPEC)

forecast


forecast

0

1

2

3

4

5

6

7

8

2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022

Source: U.S. Energy Information Administration, Short-Term Energy Outlook, September 2021Note: Black line represents 2011-2020 average (2.4 million barrels per day).

forecast

2011-2020 average

Organization of the Petroleum Exporting Countries (OPEC) surplus crude oil production capacitymillion barrels per day

forecast

30

40

50

60

70

80

90

100

Jan 2016 Jan 2017 Jan 2018 Jan 2019 Jan 2020 Jan 2021 Jan 2022


Organization for Economic Cooperation and Development (OECD)commercial inventories of crude oil and other liquidsdays of supply

monthly range from January 2016 - December 2020//

0

1.35

-1.01

-0.20

0.64

-1.5

-1.0

-0.5

0.0

0.5

1.0

1.5

2.0

2.5

3.0

3.5

2019 2020 2021 2022


Federal Gulf of Mexico (GOM)Lower 48 excluding GOMAlaskanet change

forecast

0

2

4

6

8

10

12

14

2019 2020 2021 2022

monthly history

monthly forecast

annual average

U.S. crude oil production million barrels per day


1.35

-1.01

-0.20

0.64

-1.5

-1.0

-0.5

0.0

0.5

1.0

1.5

2.0

2.5

3.0

3.5

2019 2020 2021 2022


Federal Gulf of Mexico (GOM)Lower 48 excluding GOMAlaskanet change

forecast

0

2

4

6

8

10

12

14

2019 2020 2021 2022

monthly history

monthly forecast

annual average

U.S. crude oil production million barrels per day


22

forecast

275300325350375400425450475500525550575600

Jan 2016 Jan 2017 Jan 2018 Jan 2019 Jan 2020 Jan 2021 Jan 2022Source: U.S. Energy Information Administration, Short-Term Energy Outlook, September 2021

U.S. commercial crude oil inventoriesmillion barrels

//

monthly range from January 2016 - December 2020

1.78

-0.77

-0.01

1.24

-2.00

-1.00

0.00

1.00

2.00

3.00

2019 2020 2021 2022


ethanol and biodieselnatural gas plant liquidscrude oil

net change

forecast

0

5

10

15

20

25

2019 2020 2021 2022

total monthly production forecastannual average

U.S. crude oil and liquid fuels productionmillion barrels per day


1.78

-0.77

-0.01

1.24

-2.00

-1.00

0.00

1.00

2.00

3.00

2019 2020 2021 2022


ethanol and biodieselnatural gas plant liquidscrude oil

net change

forecast

0

5

10

15

20

25

2019 2020 2021 2022

total monthly production forecastannual average

U.S. crude oil and liquid fuels productionmillion barrels per day

Source: U.S. Energy Information Administration, Short-Term Energy Outlook, September

0.03

-2.36

1.55

0.89

-3.00

-2.00

-1.00

0.00

1.00

2.00

3.00

2019 2020 2021 2022

Components of annual change

motor gasolinedistillate fueljet fuelhydrocarbon gasliquids

other fuels

forecast

0

5

10

15

20

25

30

2019 2020 2021 2022


U.S. liquid fuels product supplied(consumption)

million barrels per day


0.03

-2.36

1.55

0.89

-3.00

-2.00

-1.00

0.00

1.00

2.00

3.00

2019 2020 2021 2022



motor gasolinedistillate fueljet fuelhydrocarbon gasliquids

other fuels

forecast

0

5

10

15

20

25

30

2019 2020 2021 2022


U.S. liquid fuels product supplied(consumption) million barrels per day


forecast

6080

100120140160180200220240260280


U.S. gasoline and distillate inventoriesmillion barrels



total motor gasoline inventory

total distillate fuel inventory

forecast

-6

-4

-2

0

2

4

6

8

10

Jan 2015 Jan 2016 Jan 2017 Jan 2018 Jan 2019 Jan 2020 Jan 2021 Jan 2022Note: Petroleum product and other liquids include: gasoline, distillate fuels, hydrocarbon gas liquids, jet fuel, residual fuel oil, unfinished oils, other hydrocarbons/oxygenates, and other oils.Source: U.S. Energy Information Administration, Short-Term Energy Outlook, September 2021

U.S. net imports of crude oil and liquid fuelsmillion barrels per day

crude oil net imports

totalnet imports

petroleumproduct andother liquidsnet imports

0.460.35

0.13

0.55

-0.50

-0.25

0.00

0.25

0.50

0.75

2019 2020 2021 2022


net changenatural gasolinebutanespropaneethane

forecast

2

3

4

5

6

7

2019 2020 2021 2022

monthly production

monthly forecast

annual average

U.S. natural gas plant liquids productionmillion barrels per day

//0


0.46

0.35

0.13

0.55

-0.50

-0.25

0.00

0.25

0.50

0.75

2019 2020 2021 2022


net changenatural gasolinebutanespropaneethane

forecast

2

3

4

5

6

7

2019 2020 2021 2022

monthly production

monthly forecast

annual average

U.S. natural gas plant liquids productionmillion barrels per day

//0


022

0.13 0.09 0.14

0.26

-0.50

-0.25

0.00

0.25

0.50

0.75

2019 2020 2021 2022



net changenatural gasolineethanepropanebutanes

forecast

0

1

2

3

4

5

2019 2020 2021 2022


U.S. hydrocarbon gas liquids product supplied (consumption)million barrels per day


0.13 0.09 0.14

0.26

-0.50

-0.25

0.00

0.25

0.50

0.75

2019 2020 2021 2022



net changenatural gasolineethanepropanebutanes

forecast

0

1

2

3

4

5

2019 2020 2021 2022

monthly history

monthly forecast

annual average

U.S. hydrocarbon gas liquids product supplied (consumption)million barrels per day


-2.5

-2.0

-1.5

-1.0

-0.5

0.0

0.5

2000 2002 2004 2006 2008 2010 2012 2014 2016 2018 2020

U.S. net trade of hydrocarbon gas liquids (HGL) million barrels per day

net tradepropaneethanenatural gasolinebutanes

forecast


net importsnet exports

forecast

0

25

50

75

100

125




U.S. commercial propane inventoriesmillion barrels

Note: Excludes propylene.

9.6

-1.2

1.0

3.7

-5

0

5

10

15

2019 2020 2021 2022

Components of annual changebillion cubic feet per day

U.S. non-Gulf of Mexico U.S. Gulf of Mexiconet change

forecast

75

80

85

90

95

100

105

2019 2020 2021 2022


U.S. marketed natural gas production billion cubic feet per day


//0

9.6

-1.2

1.0

3.7

-5

0

5

10

15

2019 2020 2021 2022


U.S. non-Gulf of Mexico U.S. Gulf of Mexiconet change

forecast

75

80

85

90

95

100

105

2019 2020 2021 2022

monthly history

monthly forecast

annual average

U.S. marketed natural gas production billion cubic feet per day


2.6

-1.9

-0.70.1

-7-6-5-4-3-2-1012345

2019 2020 2021 2022


net changeindustrialelectric powerresidential and commercial

other

forecast

0102030405060708090

100110120

2019 2020 2021 2022


U.S. natural gas consumption billion cubic feet per day


2.6

-1.9

-0.70.1

-7-6-5-4-3-2-1012345

2019 2020 2021 2022


net changeindustrialelectric powerresidential and commercial

other

forecast

0102030405060708090

100110120

2019 2020 2021 2022


U.S. natural gas consumption billion cubic feet per day


22

-30-20-10

0102030

net storage builds

net storage withdrawals


forecast

-25

0

25

50

75

100

125


2016 2017 2018 2019 2020 2021 2022

U.S. natural gas production, consumption, and net importsbillion cubic feet per day

consumption

production

net trade (imports minus exports)

-30-20-10

0102030

net storage builds

net storage withdrawals


forecast

-25

0

25

50

75

100

125


2016 2017 2018 2019 2020 2021 2022

U.S. natural gas production, consumption, and net importsbillion cubic feet per day

consumption

production

net trade (imports minus exports)

-2.0-5.2 -7.5

-11.1 -12.4-25

-20

-15

-10

-5

0

5

10

2018 2019 2020 2021 2022

U.S. annual natural gas tradebillion cubic feet per day

gross importsas liquefiednatural gasby pipeline

net trade

gross exportsby pipelineas liquefied natural gas

forecast


forecast

-50%-25%

0%25%50%


Percent deviation from 2016 - 2020 average

0

1,000

2,000

3,000

4,000

5,000


U.S. working natural gas in storagebillion cubic feet

storage level forecast


forecast

-50%-25%

0%25%50%


Percent deviation from 2016 - 2020 average

0

1,000

2,000

3,000

4,000

5,000


U.S. working natural gas in storagebillion cubic feet

storage level forecast


-50

-171

66 47

-250

-200

-150

-100

-50

0

50

100

150

2019 2020 2021 2022

Components of annual changemillion short tons

Western regionAppalachian regionInterior regionnet change

forecast

0

10

20

30

40

50

60

70

80

2018 2019 2020 2021 2022

monthly history

monthly forecast

annual average

U.S. coal production million short tons


-50

-171

66 47

-250

-200

-150

-100

-50

0

50

100

150

2019 2020 2021 2022


Western regionAppalachian regionInterior regionnet change

forecast

0

10

20

30

40

50

60

70

80

2018 2019 2020 2021 2022

monthly history

monthly forecast

annual average

U.S. coal production million short tons


-102 -109

106

-17

-125-100

-75-50-25

0255075

100125

2019 2020 2021 2022


coke plantselectric powerretail and other industry

forecast

0

10

20

30

40

50

60

70

80

2018 2019 2020 2021 2022


U.S. coal consumption million short tons


-102 -109

106

-17

-125

-100

-75

-50

-25

0

25

50

75

100

125

2019 2020 2021 2022


coke plantselectric powerretail and other industry

forecast

0

10

20

30

40

50

60

70

80

2018 2019 2020 2021 2022


U.S. coal consumption million short tons


forecast

0255075

100125150175200225250


U.S. electric power coal inventoriesmillion short tons



-49

-153

112

41

-200-150-100

-500

50100150200250300

2019 2020 2021 2022

Components of annual changebillion kilowatthours

residential salesindustrial salescommercial and

transportation salesdirect usenet change

forecast

200225250275300325350375400425450

2018 2019 2020 2021 2022

monthly history

monthly forecast

annual average

U.S. electricity consumptionbillion kilowatthours

//0


-49

-153

112

41

-200

-150

-100

-50

0

50

100

150

200

250

300

2019 2020 2021 2022

Components of annual changebillion kilowatthours

residential salesindustrial salescommercial and

transportation salesdirect usenet change

forecast

200

225

250

275

300

325

350

375

400

425

450

2018 2019 2020 2021 2022

monthly history

monthly forecast

annual average

U.S. electricity consumptionbillion kilowatthours

//0


1.1%

-0.8%

2.7%

-0.1%

1.1%1.4%

3.3%

1.8%

-2%

-1%

0%

1%

2%

3%

4%

2015 2016 2017 2018 2019 2020 2021 2022

Annual growth in nominal residential electricity pricespercent

forecast

0123456789

101112131415

2015 2016 2017 2018 2019 2020 2021 2022

U.S. monthly nominal residential electricity pricecents per kilowatthour

historyforecast


1.1%

-0.8%

2.7%

-0.1%

1.1%1.4%

3.3%

1.8%

-2%

-1%

0%

1%

2%

3%

4%

2015 2016 2017 2018 2019 2020 2021 2022

Annual growth in nominal residential electricity pricespercent

forecast

0123456789

101112131415

2015 2016 2017 2018 2019 2020 2021 2022

U.S. monthly nominal residential electricity pricecents per kilowatthour

historyforecast


0%5%

10%15%20%25%30%35%40%45%50%

2011

2012

2013

2014

2015

2016

2017

2018

2019

2020

2021

2022

percent share forecast

0

1,000

2,000

3,000

4,000

2011

2012

2013

2014

2015

2016

2017

2018

2019

2020

2021

2022

U.S. electricity generation by fuel, all sectorsbillion kilowatthours

forecast


natural gas

coal

nuclearrenewables(non-hydro) hydropower 0%

5%10%15%20%25%30%35%40%45%50%

2011

2012

2013

2014

2015

2016

2017

2018

2019

2020

2021

2022

percent share forecast

0

1,000

2,000

3,000

4,000

2011

2012

2013

2014

2015

2016

2017

2018

2019

2020

2021

2022

U.S. electricity generation by fuel, all sectorsbillion kilowatthours

forecast


natural gas

coal

nuclearrenewables(non-hydro) hydropowerother source

0.09

0.360.72

1.03forecast

-0.50

-0.25

0.00

0.25

0.50

0.75

1.00

1.25

2019 2020 2021 2022

Components of annual changequadrillion British thermal units

net changesolar windhydropowerliquid biofuelsgeothermalwood biomasswaste biomass

forecast

0

2

4

6

8

10

12

14

2018 2019 2020 2021 2022

U.S. renewable energy supplyquadrillion British thermal units

Note: Hydropower excludes pumped storage generation. Liquid biofuels include ethanol and biodiesel. Other biomass includes municipal waste from biogenic sources, landfill gas, and other non-wood waste.Source: U.S. Energy Information Administration, Short-Term Energy Outlook, September 2021

0.09

0.36

0.72

1.03forecast

-0.50

-0.25

0.00

0.25

0.50

0.75

1.00

1.25

2019 2020 2021 2022

Components of annual changequadrillion British thermal units

net changesolar windhydropowerliquid biofuelsgeothermalwood biomasswaste biomass

forecast

0

2

4

6

8

10

12

14

2018 2019 2020 2021 2022

U.S. renewable energy supplyquadrillion British thermal units

Note: Hydropower excludes pumped storage generation. Liquid biofuels include ethanol and biodiesel. Other biomass includes municipal waste from biogenic sources, landfill gas, and other non-wood waste.


-135

-569

360

75

forecast

-700-600-500-400-300-200-100

0100200300400500600

2019 2020 2021 2022

Components of annual changemillion metric tons

natural gaspetroleumcoalnet change

forecast

0500

1,0001,5002,0002,5003,0003,5004,0004,5005,0005,5006,000

2018 2019 2020 2021 2022

total energy

petroleum

natural gas

coal

U.S. annual CO2 emissions by sourcemillion metric tons


-135

-569

360

75

forecast

-700-600-500-400-300-200-100

0100200300400500600

2019 2020 2021 2022

Components of annual changemillion metric tons

natural gaspetroleumcoalnet change

forecast

0500

1,0001,5002,0002,5003,0003,5004,0004,5005,0005,5006,000

2018 2019 2020 2021 2022

total energy

petroleum

natural gas

coal

U.S. annual CO2 emissions by sourcemillion metric tons


0%

2%

4%

6%

8%

10%

12%

2002 2004 2006 2008 2010 2012 2014 2016 2018 2020 2022

U.S. annual energy expendituresshare of gross domestic product


forecast

0

200

400

600

800

1,000

1,200

1,400

1,600

total summer0

50

100

150

200

250

300

350

400

April May June July August September

U.S. summer cooling degree dayspopulation-weighted

20192020202120222011-2020 average

warmer

cooler

Note: EIA calculations based on National Oceanic and Atmospheric Administration (NOAA) data. Projections reflect NOAA's 14-16 month outlook.Source: U.S. Energy Information Administration, Short-Term Energy Outlook, September 2021

0

200

400

600

800

1,000

1,200

1,400

1,600

totalsummer

0

50

100

150

200

250

300

350

400

April May June July August September

U.S. summer cooling degree dayspopulation-weighted

20192020202120222011-2020 average

warmer

cooler


0

1,000

2,000

3,000

4,000

total winter0

250

500

750

1,000

October November December January February March

2018/192019/202020/212021/22previous 10-winter average

U.S. winter heating degree dayspopulation-weighted

cooler

warmer


0

1,000

2,000

3,000

4,000

total winter0

250

500

750

1,000

October November December January February March

2018/192019/202020/212021/22previous 10-winter average

U.S. winter heating degree dayspopulation-weighted

cooler

warmer

Note: EIA calculations based on National Oceanic and Atmospheric Administration (NOAA) data. Projections reflect NOAA's 14-16 month outlook.


Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022

Energy Supply

Crude Oil Production (a)

(million barrels per day) ............................. 12.81 10.67 10.79 10.87 10.69 11.28 11.06 11.28 11.42 11.58 11.81 12.06 11.28 11.08 11.72

Dry Natural Gas Production

(billion cubic feet per day) .......................... 94.80 89.68 89.83 91.15 90.30 93.05 92.64 92.70 93.17 94.54 96.25 97.59 91.36 92.18 95.40

Coal Production

(million short tons) ..................................... 149 116 136 134 140 152 151 157 164 158 165 161 535 601 648

Energy Consumption

Liquid Fuels

(million barrels per day) ............................. 19.50 16.07 18.45 18.72 18.45 20.03 20.30 20.15 20.01 20.51 21.02 20.94 18.19 19.74 20.63

Natural Gas

(billion cubic feet per day) .......................... 99.31 70.84 76.83 86.08 99.20 72.12 74.48 84.62 96.77 70.44 75.55 87.80 83.25 82.54 82.60

Coal (b)

(million short tons) ..................................... 110 96 149 123 139 126 168 150 149 131 157 130 477 583 566

Electricity

(billion kilowatt hours per day) ................... 10.14 9.64 11.87 9.89 10.52 10.22 12.04 10.11 10.58 10.39 12.11 10.26 10.39 10.72 10.84

Renewables (c)

(quadrillion Btu) .......................................... 2.92 3.00 2.83 2.91 2.95 3.17 3.11 3.20 3.34 3.51 3.31 3.33 11.66 12.43 13.49

Total Energy Consumption (d)

(quadrillion Btu) .......................................... 25.10 20.63 23.42 23.79 25.04 23.09 24.42 24.77 25.57 23.41 24.71 25.14 92.94 97.32 98.84

Energy Prices

Crude Oil West Texas Intermediate Spot

(dollars per barrel) ...................................... 45.34 27.96 40.89 42.50 58.09 66.19 69.75 68.29 65.13 63.82 61.32 59.33 39.17 65.69 62.37

Natural Gas Henry Hub Spot

(dollars per million Btu) .............................. 1.91 1.71 2.00 2.53 3.56 2.94 4.00 4.00 4.12 3.28 3.26 3.21 2.03 3.63 3.47

Coal

(dollars per million Btu) .............................. 1.93 1.91 1.93 1.92 1.91 1.92 1.98 1.99 2.02 2.02 1.99 1.96 1.92 1.95 2.00

Macroeconomic

Real Gross Domestic Product

(billion chained 2012 dollars - SAAR) ........ 18,952 17,258 18,561 18,768 19,056 19,358 19,643 19,914 20,149 20,290 20,417 20,533 18,385 19,493 20,347

Percent change from prior year ................. 0.6 -9.1 -2.9 -2.3 0.5 12.2 5.8 6.1 5.7 4.8 3.9 3.1 -3.4 6.0 4.4

GDP Implicit Price Deflator

(Index, 2012=100) ...................................... 113.4 113.0 114.0 114.6 115.8 117.5 118.7 119.6 120.1 120.6 121.0 121.6 113.7 117.9 120.8

Percent change from prior year ................. 1.7 0.7 1.3 1.5 2.1 4.0 4.2 4.3 3.7 2.6 1.9 1.7 1.3 3.7 2.5

Real Disposable Personal Income

(billion chained 2012 dollars - SAAR) ........ 14,963 16,520 15,783 15,443 17,301 15,797 15,514 15,394 15,418 15,561 15,694 15,766 15,677 16,002 15,610

Percent change from prior year ................. 1.6 12.5 6.9 4.0 15.6 -4.4 -1.7 -0.3 -10.9 -1.5 1.2 2.4 6.2 2.1 -2.4

Manufacturing Production Index

(Index, 2017=100) ...................................... 97.6 84.2 94.2 96.7 97.3 98.6 100.4 101.7 103.4 104.5 105.2 105.9 93.2 99.5 104.7

Percent change from prior year ................. -2.7 -15.3 -5.2 -2.4 -0.3 17.1 6.6 5.2 6.2 5.9 4.8 4.1 -6.4 6.8 5.2

Weather

U.S. Heating Degree-Days ........................ 1,881 544 71 1,422 2,107 473 68 1,530 2,113 488 77 1,525 3,918 4,178 4,202

U.S. Cooling Degree-Days ........................ 69 392 931 120 49 413 875 92 45 396 848 96 1,513 1,429 1,384

Consequently, the historical data may not precisely match those published in the MER or the Annual Energy Review (AER).

Table 1. U.S. Energy Markets Summary

U.S. Energy Information Administration | Short-Term Energy Outlook - September 2021

2020 2021 2022 Year

(a) Includes lease condensate.

(b) Total consumption includes Independent Power Producer (IPP) consumption.

(c) Renewable energy includes minor components of non-marketed renewable energy that is neither bought nor sold, either directly or indirectly, as inputs to marketed energy.

EIA does not estimate or project end-use consumption of non-marketed renewable energy.

(d) The conversion from physical units to Btu is calculated using a subset of conversion factors used in the calculations of gross energy consumption in EIA’s Monthly Energy Review (MER).

(e) Refers to the refiner average acquisition cost (RAC) of crude oil.

- = no data available

Notes: EIA completed modeling and analysis for this report on September 2, 2021.

The approximate break between historical and forecast values is shown with historical data printed in bold; estimates and forecasts in italics.

Prices are not adjusted for inflation.

Historical data: Latest data available from Energy Information Administration databases supporting the following reports: Petroleum Supply Monthly , DOE/EIA-0109;

Petroleum Supply Annual , DOE/EIA-0340/2; Weekly Petroleum Status Report , DOE/EIA-0208; Petroleum Marketing Monthly , DOE/EIA-0380; Natural Gas Monthly , DOE/EIA-0130;

Electric Power Monthly , DOE/EIA-0226; Quarterly Coal Report , DOE/EIA-0121; and International Petroleum Monthly , DOE/EIA-0520.

Minor discrepancies with published historical data are due to independent rounding.

Forecasts: EIA Short-Term Integrated Forecasting System. U.S. macroeconomic forecasts are based on the IHS Markit model of the U.S. Economy.

Weather forecasts from National Oceanic and Atmospheric Administration.

Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022

Crude Oil (dollars per barrel)

West Texas Intermediate Spot Average .............................. 45.34 27.96 40.89 42.50 58.09 66.19 69.75 68.29 65.13 63.82 61.32 59.33 39.17 65.69 62.37

Brent Spot Average ............................................................. 49.97 29.52 42.97 44.34 61.12 68.91 72.67 71.29 68.63 67.32 64.98 63.33 41.69 68.61 66.04

U.S. Imported Average ........................................................ 43.75 26.24 39.87 40.69 55.27 64.74 67.84 66.25 62.88 61.56 58.88 56.83 37.22 63.95 60.02

U.S. Refiner Average Acquisition Cost ................................ 47.48 26.76 40.79 42.09 57.12 66.06 68.78 67.29 63.90 62.57 59.86 57.83 39.73 65.05 60.96

U.S. Liquid Fuels (cents per gallon)

Refiner Prices for Resale

Gasoline .......................................................................... 153 104 137 133 180 217 230 207 197 204 198 182 133 210 195

Diesel Fuel ....................................................................... 160 97 124 133 178 204 211 214 206 205 201 196 129 203 202

Fuel Oil ............................................................................ 160 87 113 121 162 180 195 208 203 195 190 188 125 192 197

Refiner Prices to End Users

Jet Fuel ............................................................................ 165 85 116 125 163 182 192 200 202 202 198 195 131 186 199

No. 6 Residual Fuel Oil (a) ............................................... 177 93 116 119 162 181 168 161 152 151 144 138 126 168 146

Retail Prices Including Taxes

Gasoline Regular Grade (b) .............................................. 241 194 218 215 256 297 314 291 273 285 278 264 218 291 275

Gasoline All Grades (b) .................................................... 251 203 227 224 265 306 324 303 286 298 292 278 227 301 289

On-highway Diesel Fuel ................................................... 289 243 243 247 290 321 331 324 315 307 307 304 256 317 308

Heating Oil ....................................................................... 280 200 214 230 272 283 302 332 326 303 285 284 244 296 304

Natural Gas

Henry Hub Spot (dollars per thousand cubic feet) ................ 1.98 1.77 2.07 2.63 3.70 3.06 4.15 4.16 4.28 3.41 3.38 3.34 2.11 3.77 3.60

Henry Hub Spot (dollars per million Btu) ............................. 1.91 1.71 2.00 2.53 3.56 2.94 4.00 4.00 4.12 3.28 3.26 3.21 2.03 3.63 3.47

U.S. Retail Prices (dollars per thousand cubic feet)

Industrial Sector ............................................................... 3.52 2.85 2.88 3.77 5.72 4.06 4.91 5.38 5.69 4.60 4.33 4.52 3.29 5.05 4.81

Commercial Sector ........................................................... 7.13 7.63 8.49 7.53 7.55 8.84 9.66 8.88 8.73 9.03 9.13 8.03 7.48 8.39 8.61

Residential Sector ............................................................ 9.46 11.89 17.65 10.60 9.79 13.87 18.86 12.09 10.97 13.59 17.94 11.01 10.83 11.73 11.85

U.S. Electricity

Power Generation Fuel Costs (dollars per million Btu)

Coal ................................................................................. 1.93 1.91 1.93 1.92 1.91 1.92 1.98 1.99 2.02 2.02 1.99 1.96 1.92 1.95 2.00

Natural Gas ..................................................................... 2.39 2.08 2.26 2.87 7.26 3.27 4.16 4.42 4.76 3.53 3.42 3.56 2.39 4.69 3.75

Residual Fuel Oil (c) ......................................................... 12.15 6.65 8.85 8.90 11.28 12.99 13.03 13.01 13.03 13.33 12.32 11.90 9.15 12.72 12.70

Distillate Fuel Oil .............................................................. 13.27 8.39 10.37 10.54 13.59 15.40 15.85 16.52 16.15 16.07 15.16 15.17 10.73 14.93 15.59

Retail Prices (cents per kilowatthour)

Industrial Sector ............................................................... 6.38 6.63 7.08 6.53 7.15 6.90 7.26 6.58 6.96 6.84 7.16 6.57 6.66 6.97 6.89

Commercial Sector ........................................................... 10.33 10.63 10.97 10.62 11.11 11.07 11.52 11.09 11.41 11.21 11.44 10.96 10.65 11.21 11.26

Residential Sector ............................................................ 12.90 13.24 13.35 13.25 13.09 13.78 13.89 13.76 13.68 14.14 13.97 13.73 13.20 13.63 13.88

Table 2. Energy Prices


2020 2021 2022 Year

Forecasts: EIA Short-Term Integrated Forecasting System.

(a) Average for all sulfur contents.

(b) Average self-service cash price.

(c) Includes fuel oils No. 4, No. 5, No. 6, and topped crude.




Prices are not adjusted for inflation; prices exclude taxes unless otherwise noted.

Historical data: Latest data available from Energy Information Administration databases supporting the following reports: Petroleum Marketing Monthly , DOE/EIA-0380;

Weekly Petroleum Status Report , DOE/EIA-0208; Natural Gas Monthly , DOE/EIA-0130; Electric Power Monthly , DOE/EIA-0226; and Monthly Energy Review , DOE/EIA-0035.

Natural gas Henry Hub and WTI crude oil spot prices from Reuter's News Service (http://www.reuters.com).


Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022

Supply (million barrels per day) (a)

OECD ................................................ 33.05 29.27 29.95 30.66 30.18 30.89 31.22 31.90 32.17 32.45 32.79 33.37 30.73 31.05 32.70

U.S. (50 States) .............................. 20.33 17.44 18.29 18.29 17.62 19.05 18.76 19.12 19.38 19.81 20.26 20.58 18.58 18.64 20.01

Canada ........................................... 5.64 4.90 4.94 5.54 5.63 5.41 5.64 5.81 5.84 5.81 5.83 5.86 5.26 5.62 5.83

Mexico ............................................ 2.00 1.94 1.91 1.90 1.93 1.95 1.86 1.90 1.88 1.84 1.81 1.77 1.94 1.91 1.82

Other OECD ................................... 5.08 4.99 4.81 4.93 5.00 4.48 4.96 5.07 5.08 5.00 4.89 5.16 4.95 4.88 5.03

Non-OECD ........................................ 67.69 63.02 61.06 62.08 62.61 63.90 66.08 67.70 67.62 68.63 69.41 69.32 63.45 65.09 68.75

OPEC .............................................. 33.50 30.72 28.65 30.00 30.37 30.78 32.30 33.53 33.71 33.80 33.97 34.01 30.71 31.76 33.87

Crude Oil Portion ......................... 28.28 25.65 23.63 24.88 25.08 25.51 26.94 28.10 28.12 28.34 28.45 28.45 25.60 26.42 28.34

Other Liquids (b) .......................... 5.22 5.07 5.02 5.12 5.29 5.27 5.36 5.43 5.59 5.47 5.52 5.56 5.11 5.34 5.53

Eurasia ............................................ 14.72 13.16 12.70 13.12 13.38 13.62 13.59 14.19 14.46 14.66 14.77 14.97 13.42 13.70 14.72

China ............................................... 4.96 4.91 4.95 4.90 5.05 5.09 5.04 5.06 5.05 5.08 5.08 5.13 4.93 5.06 5.08

Other Non-OECD ........................... 14.51 14.22 14.75 14.06 13.82 14.42 15.15 14.91 14.40 15.08 15.59 15.21 14.39 14.58 15.07

Total World Supply ............................ 100.74 92.30 91.01 92.74 92.80 94.80 97.30 99.60 99.79 101.08 102.20 102.68 94.18 96.14 101.45

Non-OPEC Supply ............................. 67.24 61.57 62.36 62.74 62.43 64.02 64.99 66.06 66.07 67.28 68.23 68.68 63.47 64.39 67.57

Consumption (million barrels per day) (c)

OECD ................................................ 45.50 37.45 42.27 42.84 42.30 43.68 45.48 45.89 45.51 45.25 46.30 46.36 42.02 44.35 45.86

U.S. (50 States) .............................. 19.50 16.07 18.45 18.72 18.45 20.03 20.30 20.15 20.01 20.51 21.02 20.94 18.19 19.74 20.63

U.S. Territories ............................... 0.17 0.15 0.16 0.17 0.20 0.18 0.18 0.19 0.20 0.18 0.19 0.20 0.16 0.19 0.19

Canada ........................................... 2.42 1.97 2.25 2.14 2.12 2.09 2.29 2.31 2.27 2.22 2.32 2.31 2.19 2.20 2.28

Europe ............................................ 13.34 11.01 12.88 12.51 11.90 12.51 13.73 13.55 13.14 13.27 13.59 13.26 12.43 12.93 13.31

Japan .............................................. 3.78 2.93 3.06 3.53 3.73 3.01 2.99 3.38 3.63 2.96 3.04 3.35 3.33 3.27 3.24

Other OECD ................................... 6.30 5.34 5.47 5.77 5.89 5.86 5.98 6.30 6.25 6.10 6.14 6.31 5.72 6.01 6.20

Non-OECD ........................................ 50.33 47.44 51.21 52.59 52.37 52.81 53.07 53.88 54.08 55.37 55.49 55.64 50.40 53.04 55.15

Eurasia ............................................ 4.86 4.48 5.28 5.17 4.92 5.01 5.41 5.25 5.04 5.12 5.51 5.37 4.95 5.15 5.26

Europe ............................................ 0.71 0.69 0.71 0.72 0.73 0.73 0.74 0.75 0.74 0.74 0.74 0.75 0.71 0.74 0.74

China ............................................... 13.89 14.08 14.65 15.11 15.26 15.46 14.77 15.30 15.75 16.01 15.71 15.99 14.43 15.20 15.86

Other Asia ....................................... 13.35 11.63 12.59 13.61 13.78 13.35 13.21 13.89 14.30 14.51 14.10 14.53 12.80 13.56 14.36

Other Non-OECD ........................... 17.53 16.55 17.98 17.99 17.67 18.26 18.94 18.69 18.24 19.00 19.42 19.00 17.51 18.39 18.92

Total World Consumption .................. 95.83 84.90 93.47 95.43 94.66 96.49 98.55 99.77 99.59 100.62 101.79 102.00 92.42 97.38 101.01

Total Crude Oil and Other Liquids Inventory Net Withdrawals (million barrels per day)

U.S. (50 States) ................................. -0.49 -1.67 0.53 0.91 0.47 0.51 0.33 0.54 -0.11 -0.69 -0.08 0.40 -0.18 0.46 -0.12

Other OECD ...................................... -0.51 -1.16 0.04 0.69 0.76 0.10 0.30 -0.12 -0.03 0.07 -0.10 -0.34 -0.23 0.26 -0.10

Other Stock Draws and Balance ....... -3.91 -4.57 1.90 1.09 0.64 1.08 0.62 -0.25 -0.06 0.16 -0.23 -0.74 -1.36 0.52 -0.22

Total Stock Draw ............................ -4.91 -7.40 2.46 2.69 1.87 1.69 1.25 0.17 -0.20 -0.46 -0.41 -0.68 -1.76 1.24 -0.44

End-of-period Commercial Crude Oil and Other Liquids Inventories (million barrels)

U.S. Commercial Inventory ............... 1,327 1,458 1,423 1,343 1,302 1,271 1,241 1,211 1,221 1,284 1,291 1,265 1,343 1,211 1,265

OECD Commercial Inventory ............ 2,970 3,206 3,168 3,025 2,916 2,876 2,818 2,800 2,812 2,869 2,885 2,890 3,025 2,800 2,890

OECD = Organization for Economic Cooperation and Development: Australia, Austria, Belgium, Canada, Chile, the Czech Republic, Denmark, Estonia, Finland,

Table 3a. International Petroleum and Other Liquids Production, Consumption, and Inventories


2020 2021 2022 Year

(a) Supply includes production of crude oil (including lease condensates), natural gas plant liquids, biofuels, other liquids, and refinery processing gains.

(b) Includes lease condensate, natural gas plant liquids, other liquids, and refinery processing gain. Includes other unaccounted-for liquids.

(c) Consumption of petroleum by the OECD countries is synonymous with "petroleum product supplied," defined in the glossary of the EIA Petroleum Supply Monthly ,

DOE/EIA-0109. Consumption of petroleum by the non-OECD countries is "apparent consumption," which includes internal consumption, refinery fuel and loss, and bunkering.


Historical data: Latest data available from Energy Information Administration international energy statistics.



France, Germany, Greece, Hungary, Iceland, Ireland, Israel, Italy, Japan, Latvia, Lithuania, Luxembourg, Mexico, the Netherlands, New Zealand, Norway,

Poland, Portugal, Slovakia, Slovenia, South Korea, Spain, Sweden, Switzerland, Turkey, the United Kingdom, the United States.

OPEC = Organization of the Petroleum Exporting Countries: Algeria, Angola, Congo (Brazzaville), Equatorial Guinea, Gabon, Iran, Iraq, Kuwait, Libya, Nigeria, Saudi Arabia,

the United Arab Emirates, Venezuela.



Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022

North America ....................................................... 27.97 24.28 25.14 25.73 25.18 26.41 26.25 26.83 27.09 27.46 27.90 28.20 25.78 26.17 27.67

Canada .................................................................... 5.64 4.90 4.94 5.54 5.63 5.41 5.64 5.81 5.84 5.81 5.83 5.86 5.26 5.62 5.83

Mexico ..................................................................... 2.00 1.94 1.91 1.90 1.93 1.95 1.86 1.90 1.88 1.84 1.81 1.77 1.94 1.91 1.82

United States ........................................................... 20.33 17.44 18.29 18.29 17.62 19.05 18.76 19.12 19.38 19.81 20.26 20.58 18.58 18.64 20.01

Central and South America ................................. 6.01 6.05 6.63 5.89 5.61 6.26 6.93 6.62 6.10 6.82 7.36 7.01 6.15 6.36 6.83

Argentina ................................................................. 0.69 0.60 0.64 0.62 0.63 0.67 0.70 0.69 0.71 0.72 0.75 0.73 0.64 0.67 0.73

Brazil ....................................................................... 3.44 3.89 4.29 3.52 3.23 3.90 4.46 4.14 3.53 4.36 4.75 4.28 3.79 3.94 4.23

Colombia .................................................................. 0.90 0.78 0.77 0.79 0.77 0.74 0.77 0.78 0.84 0.72 0.74 0.78 0.81 0.77 0.77

Ecuador ................................................................... 0.54 0.36 0.52 0.51 0.51 0.50 0.52 0.53 0.53 0.53 0.53 0.53 0.48 0.51 0.53

Other Central and S. America .................................. 0.45 0.42 0.41 0.45 0.47 0.45 0.49 0.49 0.49 0.50 0.59 0.69 0.43 0.47 0.57

Europe ................................................................... 4.44 4.35 4.16 4.30 4.38 3.91 4.34 4.44 4.45 4.36 4.25 4.53 4.31 4.27 4.40

Norway .................................................................... 2.05 2.00 1.96 2.02 2.11 1.90 2.07 2.18 2.19 2.13 2.13 2.29 2.01 2.07 2.18

United Kingdom ....................................................... 1.17 1.16 0.99 1.06 1.07 0.82 1.05 1.04 1.05 1.03 0.93 1.03 1.10 1.00 1.01

Eurasia ................................................................... 14.72 13.16 12.70 13.12 13.38 13.62 13.59 14.19 14.46 14.66 14.77 14.97 13.42 13.70 14.72

Azerbaijan ................................................................ 0.76 0.69 0.66 0.69 0.74 0.69 0.73 0.78 0.81 0.80 0.78 0.81 0.70 0.74 0.80

Kazakhstan .............................................................. 2.06 1.86 1.71 1.81 1.87 1.86 1.73 1.92 1.98 1.98 1.93 2.00 1.86 1.84 1.97

Russia ..................................................................... 11.54 10.25 9.97 10.26 10.43 10.72 10.79 11.12 11.30 11.51 11.69 11.80 10.50 10.77 11.57

Turkmenistan ........................................................... 0.25 0.25 0.25 0.25 0.24 0.24 0.24 0.24 0.23 0.23 0.23 0.23 0.25 0.24 0.23

Other Eurasia ........................................................... 0.11 0.11 0.11 0.11 0.10 0.10 0.11 0.13 0.14 0.14 0.14 0.14 0.11 0.11 0.14

Middle East ............................................................ 3.16 3.13 3.09 3.13 3.15 3.18 3.19 3.22 3.26 3.26 3.26 3.25 3.13 3.18 3.26

Oman ....................................................................... 1.01 0.95 0.92 0.95 0.96 0.97 0.99 1.02 1.03 1.03 1.03 1.03 0.96 0.98 1.03

Qatar ....................................................................... 1.84 1.87 1.88 1.88 1.89 1.91 1.92 1.92 1.94 1.94 1.94 1.94 1.87 1.91 1.94

Asia and Oceania ................................................. 9.45 9.17 9.21 9.17 9.32 9.26 9.28 9.33 9.31 9.32 9.30 9.31 9.25 9.30 9.31

Australia ................................................................... 0.49 0.50 0.50 0.49 0.47 0.42 0.49 0.48 0.48 0.48 0.48 0.48 0.49 0.47 0.48

China ....................................................................... 4.96 4.91 4.95 4.90 5.05 5.09 5.04 5.06 5.05 5.08 5.08 5.13 4.93 5.06 5.08

India ......................................................................... 0.96 0.90 0.92 0.92 0.92 0.92 0.93 0.93 0.93 0.91 0.91 0.91 0.92 0.93 0.91

Indonesia ................................................................. 0.92 0.90 0.88 0.89 0.88 0.86 0.88 0.87 0.87 0.86 0.85 0.84 0.90 0.87 0.85

Malaysia .................................................................. 0.73 0.62 0.64 0.65 0.66 0.63 0.60 0.63 0.63 0.62 0.61 0.61 0.66 0.63 0.62

Vietnam ................................................................... 0.23 0.22 0.21 0.21 0.21 0.21 0.21 0.21 0.20 0.20 0.20 0.19 0.22 0.21 0.20

Africa ..................................................................... 1.48 1.44 1.42 1.40 1.40 1.39 1.40 1.43 1.40 1.40 1.39 1.39 1.43 1.41 1.39

Egypt ....................................................................... 0.62 0.61 0.60 0.58 0.58 0.60 0.64 0.64 0.61 0.61 0.61 0.61 0.60 0.61 0.61

South Sudan ............................................................ 0.15 0.15 0.17 0.17 0.16 0.16 0.16 0.18 0.18 0.18 0.18 0.18 0.16 0.16 0.18

Total non-OPEC liquids ......................................... 67.24 61.57 62.36 62.74 62.43 64.02 64.99 66.06 66.07 67.28 68.23 68.68 63.47 64.39 67.57

OPEC non-crude liquids ...................................... 5.22 5.07 5.02 5.12 5.29 5.27 5.36 5.43 5.59 5.47 5.52 5.56 5.11 5.34 5.53

Non-OPEC + OPEC non-crude ............................ 72.46 66.65 67.38 67.86 67.71 69.29 70.36 71.50 71.66 72.75 73.75 74.23 68.58 69.73 73.11

Unplanned non-OPEC Production Outages ......... 0.18 0.92 0.72 0.55 0.68 0.32 - - - - - - 0.59 - -

Table 3b. Non-OPEC Petroleum and Other Liquids Production (million barrels per day)


2020 2021 2022 Year

Not all countries are shown in each region and sum of reported country volumes may not equal regional volumes.





OPEC = Organization of the Petroleum Exporting Countries: Algeria, Angola, Congo (Brazzaville), Equatorial Guinea, Gabon, Iran, Iraq, Kuwait, Libya, Nigeria, Saudi Arabia,

the United Arab Emirates, Venezuela.



Supply includes production of crude oil (including lease condensates), natural gas plant liquids, biofuels, other liquids, and refinery processing gains.

Table 3c. OPEC Crude Oil (excluding condensates) Production (million barrels per day)

Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022

Crude Oil

Algeria ............................................................... 1.02 0.90 0.84 0.86 0.87 0.88 - - - - - - 0.90 - -

Angola ............................................................... 1.35 1.27 1.19 1.13 1.11 1.08 - - - - - - 1.23 - -

Congo (Brazzaville) .......................................... 0.29 0.29 0.28 0.26 0.28 0.27 - - - - - - 0.28 - -

Equatorial Guinea ............................................. 0.13 0.12 0.11 0.11 0.11 0.12 - - - - - - 0.11 - -

Gabon ............................................................... 0.19 0.18 0.15 0.17 0.16 0.17 - - - - - - 0.17 - -

Iran .................................................................... 2.02 1.97 1.90 1.95 2.18 2.47 - - - - - - 1.96 - -

Iraq .................................................................... 4.56 4.16 3.70 3.84 3.94 3.98 - - - - - - 4.06 - -

Kuwait ............................................................... 2.77 2.48 2.25 2.30 2.33 2.36 - - - - - - 2.45 - -

Libya ................................................................. 0.35 0.08 0.11 0.92 1.18 1.16 - - - - - - 0.36 - -

Nigeria .............................................................. 1.72 1.55 1.44 1.44 1.31 1.32 - - - - - - 1.54 - -

Saudi Arabia ..................................................... 9.80 9.28 8.77 9.01 8.49 8.53 - - - - - - 9.21 - -

United Arab Emirates ....................................... 3.30 2.88 2.55 2.50 2.61 2.65 - - - - - - 2.81 - -

Venezuela ......................................................... 0.77 0.50 0.35 0.40 0.52 0.53 - - - - - - 0.50 - -

OPEC Total .................................................... 28.28 25.65 23.63 24.88 25.08 25.51 26.94 28.10 28.12 28.34 28.45 28.45 25.60 26.42 28.34

Other Liquids (a) ................................................ 5.22 5.07 5.02 5.12 5.29 5.27 5.36 5.43 5.59 5.47 5.52 5.56 5.11 5.34 5.53

Total OPEC Supply ............................................ 33.50 30.72 28.65 30.00 30.37 30.78 32.30 33.53 33.71 33.80 33.97 34.01 30.71 31.76 33.87

Crude Oil Production Capacity

Middle East ....................................................... 25.61 26.02 26.06 26.22 26.55 26.85 26.91 27.18 27.38 27.39 27.39 27.39 25.98 26.88 27.39

Other ................................................................. 5.82 5.60 5.48 6.33 6.73 6.71 6.66 5.99 5.92 5.94 5.95 5.95 5.81 6.52 5.94

OPEC Total .................................................... 31.43 31.63 31.54 32.56 33.28 33.56 33.57 33.17 33.31 33.32 33.34 33.35 31.79 33.39 33.33

Surplus Crude Oil Production Capacity

Middle East ....................................................... 3.15 5.27 6.90 6.62 7.00 6.87 5.58 4.99 5.11 4.92 4.82 4.82 5.49 6.10 4.92

Other ................................................................. 0.00 0.71 1.02 1.06 1.19 1.18 1.05 0.08 0.07 0.07 0.07 0.07 0.70 0.87 0.07

OPEC Total .................................................... 3.15 5.98 7.92 7.68 8.19 8.06 6.63 5.07 5.18 4.99 4.89 4.90 6.19 6.98 4.99

Unplanned OPEC Production Outages .......... 3.72 4.18 4.35 3.45 2.73 2.38 - - - - - - 3.92 - -

(a) Includes lease condensate, natural gas plant liquids, other liquids, refinery processing gain, and other unaccounted-for liquids.


2020 2021 2022 Year



OPEC = Organization of the Petroleum Exporting Countries: Iran, Iraq, Kuwait, Saudi Arabia, and the United Arab Emirates (Middle East); Algeria, Angola, Congo (Brazzaville), Equatorial Guinea,

Gabon, Libya, Nigeria, and Venezuela (Other).



Forecasts are not published for individual OPEC countries.


Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022

North America ........................................................ 23.77 19.44 22.21 22.44 22.20 23.84 24.48 24.37 24.12 24.59 25.19 25.10 21.97 23.73 24.75

Canada .................................................................... 2.42 1.97 2.25 2.14 2.12 2.09 2.29 2.31 2.27 2.22 2.32 2.31 2.19 2.20 2.28

Mexico ..................................................................... 1.85 1.40 1.50 1.58 1.62 1.71 1.88 1.90 1.82 1.84 1.83 1.84 1.58 1.78 1.84

United States ........................................................... 19.50 16.07 18.45 18.72 18.45 20.03 20.30 20.15 20.01 20.51 21.02 20.94 18.19 19.74 20.63

Central and South America ................................. 6.13 5.60 6.03 6.31 6.18 6.30 6.56 6.60 6.40 6.56 6.70 6.71 6.02 6.41 6.59

Brazil ....................................................................... 2.89 2.67 2.97 3.06 2.97 3.08 3.22 3.23 3.06 3.14 3.25 3.25 2.90 3.13 3.18

Europe ................................................................... 14.04 11.70 13.59 13.23 12.63 13.24 14.47 14.30 13.88 14.01 14.33 14.01 13.14 13.67 14.06

Eurasia ................................................................... 4.86 4.48 5.28 5.17 4.92 5.01 5.41 5.25 5.04 5.12 5.51 5.37 4.95 5.15 5.26

Russia ..................................................................... 3.65 3.33 4.04 3.92 3.71 3.82 4.15 3.99 3.80 3.90 4.23 4.08 3.74 3.92 4.01

Middle East ............................................................ 7.90 7.43 8.43 8.05 7.80 8.20 8.81 8.31 8.05 8.63 9.02 8.37 7.95 8.28 8.52

Asia and Oceania ................................................. 34.95 32.20 33.86 35.94 36.60 35.55 34.56 36.47 37.62 37.23 36.64 37.85 34.24 35.79 37.33

China ....................................................................... 13.89 14.08 14.65 15.11 15.26 15.46 14.77 15.30 15.75 16.01 15.71 15.99 14.43 15.20 15.86

Japan ....................................................................... 3.78 2.93 3.06 3.53 3.73 3.01 2.99 3.38 3.63 2.96 3.04 3.35 3.33 3.27 3.24

India ......................................................................... 4.83 3.76 4.17 4.93 5.00 4.45 4.51 4.88 5.15 5.21 4.86 5.16 4.42 4.71 5.10

Africa ..................................................................... 4.18 4.05 4.07 4.29 4.33 4.35 4.25 4.47 4.48 4.49 4.41 4.60 4.15 4.35 4.50

Total OECD Liquid Fuels Consumption ............... 45.50 37.45 42.27 42.84 42.30 43.68 45.48 45.89 45.51 45.25 46.30 46.36 42.02 44.35 45.86

Total non-OECD Liquid Fuels Consumption ........ 50.33 47.44 51.21 52.59 52.37 52.81 53.07 53.88 54.08 55.37 55.49 55.64 50.40 53.04 55.15

Total World Liquid Fuels Consumption ............... 95.83 84.90 93.47 95.43 94.66 96.49 98.55 99.77 99.59 100.62 101.79 102.00 92.42 97.38 101.01

Real Gross Domestic Product (a)

World Index, 2015 Q1 = 100 .................................... 110.3 107.6 112.4 113.6 115.9 117.1 118.1 119.3 122.4 123.2 123.8 124.4 111.0 117.6 123.5

Percent change from prior year ............................. -3.3 -6.1 -2.4 -1.7 5.1 8.8 5.1 5.0 5.6 5.2 4.9 4.3 -3.4 6.0 5.0

OECD Index, 2015 = 100 ......................................... 103.7 109.1 113.8

Percent change from prior year ............................. -4.7 5.3 4.3

Non-OECD Index, 2015 = 100 ................................. 116.0 123.4 130.1

Percent change from prior year ............................. -2.3 6.4 5.4

Nominal U.S. Dollar Index (b)

Index, 2015 Q1 = 100 .............................................. 111.7 115.9 111.5 108.3 106.8 106.3 107.4 108.0 108.1 108.1 108.0 107.9 111.9 107.1 108.0

Percent change from prior year ............................. 2.8 5.8 0.9 -1.9 -4.4 -8.3 -3.7 -0.3 1.3 1.7 0.5 -0.1 1.9 -4.2 0.8

Poland, Portugal, Slovakia, Slovenia, South Korea, Spain, Sweden, Switzerland, Turkey, the United Kingdom, the United States.

Table 3d. World Petroleum and Other Liquids Consumption (million barrels per day)


2020 2021 2022

(a) GDP values for the individual countries in the indexes are converted to U.S. dollars at purchasing power parity and then summed to create values for the world, OECD, and non-OECD. Historical and

forecast data are from Oxford Economics, and quarterly values are reindexed to 2015 Q1 by EIA.

(b) Data source is the Board of Governors of the U.S. Federal Reserve System Nominal Broad Trade-Weighted Dollar Index. An increase in the index indicates an appreciation of the U.S. dollar against a

basket of currencies and a decrese in the index indicates a depreciation of the U.S. dollar against a basket of currencies. Historical and forecast data are from Oxford Economics, and quarterly values are

reindexed to 2015 Q1 by EIA.


OECD = Organization for Economic Cooperation and Development: Australia, Austria, Belgium, Canada, Chile, the Czech Republic, Denmark, Estonia, Finland,

France, Germany, Greece, Hungary, Iceland, Ireland, Israel, Italy, Japan, Latvia, Lithuania, Luxembourg, Mexico, the Netherlands, New Zealand, Norway,






Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022

Supply (million barrels per day)

Crude Oil Supply

Domestic Production (a) .................................................. 12.81 10.67 10.79 10.87 10.69 11.28 11.06 11.28 11.42 11.58 11.81 12.06 11.28 11.08 11.72

Alaska .......................................................................... 0.48 0.41 0.44 0.46 0.46 0.44 0.40 0.44 0.43 0.42 0.39 0.43 0.45 0.43 0.42

Federal Gulf of Mexico (b) ............................................ 1.99 1.66 1.43 1.50 1.80 1.80 1.52 1.73 1.76 1.73 1.74 1.78 1.64 1.71 1.75

Lower 48 States (excl GOM) ........................................ 10.35 8.60 8.92 8.91 8.44 9.04 9.14 9.12 9.22 9.43 9.67 9.86 9.19 8.94 9.55

Crude Oil Net Imports (c) ................................................. 2.89 3.06 2.24 2.50 2.87 2.96 3.60 3.49 3.77 4.71 4.82 3.84 2.67 3.23 4.29

SPR Net Withdrawals ...................................................... 0.00 -0.23 0.15 0.04 0.00 0.18 0.00 0.22 0.00 0.00 0.00 0.10 -0.01 0.10 0.03

Commercial Inventory Net Withdrawals ........................... -0.56 -0.54 0.38 0.13 -0.18 0.59 0.22 -0.09 -0.31 -0.03 0.27 -0.02 -0.14 0.14 -0.02

Crude Oil Adjustment (d) ................................................. 0.63 0.20 0.46 0.36 0.42 0.63 0.50 0.16 0.22 0.22 0.23 0.16 0.41 0.43 0.21

Total Crude Oil Input to Refineries ...................................... 15.77 13.16 14.02 13.90 13.81 15.65 15.39 15.06 15.09 16.48 17.12 16.14 14.21 14.98 16.21

Other Supply

Refinery Processing Gain ................................................ 1.02 0.82 0.93 0.92 0.84 0.97 1.00 1.04 1.05 1.09 1.14 1.13 0.92 0.96 1.10

Natural Gas Plant Liquids Production .............................. 5.17 4.96 5.34 5.22 4.86 5.46 5.40 5.50 5.62 5.81 5.95 6.04 5.17 5.30 5.86

Renewables and Oxygenate Production (e) ..................... 1.11 0.81 1.03 1.07 1.03 1.13 1.09 1.09 1.08 1.11 1.13 1.13 1.01 1.09 1.12

Fuel Ethanol Production ............................................... 1.02 0.70 0.92 0.97 0.90 0.99 0.99 0.98 0.98 1.01 1.02 1.01 0.91 0.97 1.01

Petroleum Products Adjustment (f) .................................. 0.22 0.19 0.20 0.19 0.19 0.22 0.21 0.21 0.20 0.22 0.22 0.22 0.20 0.21 0.22

Product Net Imports (c) ................................................... -3.86 -2.96 -3.07 -3.33 -2.94 -3.13 -2.90 -3.15 -3.24 -3.53 -4.20 -4.04 -3.30 -3.03 -3.76

Hydrocarbon Gas Liquids ............................................. -1.95 -1.84 -1.83 -2.06 -2.02 -2.23 -2.24 -2.15 -2.14 -2.25 -2.31 -2.27 -1.92 -2.16 -2.24

Unfinished Oils ............................................................. 0.37 0.23 0.35 0.18 0.14 0.25 0.40 0.30 0.21 0.26 0.30 0.20 0.29 0.27 0.24

Other HC/Oxygenates .................................................. -0.09 -0.04 -0.04 -0.04 -0.08 -0.04 -0.07 -0.08 -0.09 -0.08 -0.08 -0.09 -0.05 -0.07 -0.08

Motor Gasoline Blend Comp. ........................................ 0.40 0.37 0.49 0.44 0.55 0.79 0.46 0.21 0.54 0.76 0.42 0.21 0.42 0.50 0.48

Finished Motor Gasoline ............................................... -0.71 -0.41 -0.58 -0.76 -0.66 -0.66 -0.32 -0.60 -0.74 -0.60 -0.63 -0.71 -0.62 -0.56 -0.67

Jet Fuel ........................................................................ -0.07 0.09 0.12 0.08 0.03 0.09 0.14 0.13 -0.04 -0.03 0.04 0.12 0.05 0.10 0.02

Distillate Fuel Oil .......................................................... -1.14 -0.86 -1.16 -0.72 -0.49 -0.90 -0.83 -0.45 -0.54 -0.98 -1.30 -1.02 -0.97 -0.67 -0.96

Residual Fuel Oil .......................................................... -0.02 -0.01 0.05 0.05 0.08 0.05 0.07 0.08 0.02 -0.03 -0.02 0.07 0.02 0.07 0.01

Other Oils (g) ............................................................... -0.64 -0.49 -0.48 -0.48 -0.49 -0.49 -0.51 -0.58 -0.46 -0.58 -0.64 -0.55 -0.52 -0.52 -0.56

Product Inventory Net Withdrawals .................................. 0.06 -0.90 0.00 0.73 0.65 -0.26 0.11 0.41 0.20 -0.66 -0.34 0.31 -0.02 0.23 -0.12

Total Supply ....................................................................... 19.50 16.07 18.45 18.72 18.43 20.03 20.30 20.15 20.01 20.51 21.02 20.94 18.19 19.74 20.63

Consumption (million barrels per day)

Hydrocarbon Gas Liquids ................................................ 3.37 2.85 3.01 3.68 3.40 3.33 3.09 3.63 3.84 3.35 3.41 3.89 3.23 3.36 3.62

Unfinished Oils ................................................................ 0.18 0.12 0.03 0.03 0.05 0.03 0.01 0.00 0.00 0.00 0.00 0.00 0.09 0.02 0.00

Motor Gasoline ................................................................ 8.51 7.12 8.51 8.06 8.00 9.07 9.27 8.76 8.50 9.21 9.35 8.87 8.05 8.78 8.98

Fuel Ethanol blended into Motor Gasoline .................... 0.85 0.73 0.87 0.85 0.82 0.93 0.93 0.89 0.86 0.94 0.95 0.92 0.82 0.89 0.92

Jet Fuel ........................................................................... 1.56 0.69 0.97 1.09 1.13 1.34 1.54 1.52 1.47 1.57 1.72 1.72 1.08 1.38 1.62

Distillate Fuel Oil ............................................................. 4.02 3.49 3.70 3.94 3.97 3.93 3.97 4.13 4.17 4.12 4.10 4.24 3.79 4.00 4.16

Residual Fuel Oil ............................................................. 0.17 0.11 0.32 0.22 0.26 0.25 0.32 0.27 0.27 0.25 0.29 0.28 0.21 0.28 0.27

Other Oils (g) .................................................................. 1.69 1.68 1.92 1.71 1.63 2.08 2.11 1.84 1.76 2.01 2.16 1.93 1.75 1.92 1.97

Total Consumption ............................................................. 19.50 16.07 18.45 18.72 18.45 20.03 20.30 20.15 20.01 20.51 21.02 20.94 18.19 19.74 20.63

Total Petroleum and Other Liquids Net Imports ............. -0.97 0.11 -0.83 -0.84 -0.07 -0.16 0.70 0.34 0.53 1.18 0.61 -0.20 -0.63 0.20 0.53

End-of-period Inventories (million barrels)

Commercial Inventory

Crude Oil (excluding SPR) ............................................... 483.3 532.7 497.7 485.5 501.9 448.0 427.8 435.7 463.7 466.4 441.8 443.9 485.5 435.7 443.9

Hydrocarbon Gas Liquids ................................................ 182.9 235.7 298.7 228.2 168.6 195.8 225.7 175.6 137.6 191.6 238.8 200.6 228.2 175.6 200.6

Unfinished Oils ................................................................ 101.9 92.5 81.4 77.6 93.3 93.0 89.0 82.8 93.3 91.1 90.0 83.1 77.6 82.8 83.1

Other HC/Oxygenates ..................................................... 33.4 25.4 24.6 29.7 29.1 27.5 26.7 27.0 29.0 27.8 27.5 27.8 29.7 27.0 27.8

Total Motor Gasoline ....................................................... 261.8 254.5 227.6 243.4 237.6 237.2 218.7 232.8 241.6 246.5 233.8 248.7 243.4 232.8 248.7

Finished Motor Gasoline ............................................... 22.6 23.5 22.5 25.4 20.3 18.6 21.4 24.3 24.1 23.9 23.1 26.1 25.4 24.3 26.1

Motor Gasoline Blend Comp. ........................................ 239.2 231.0 205.0 218.0 217.4 218.6 197.3 208.5 217.5 222.6 210.6 222.7 218.0 208.5 222.7

Jet Fuel ........................................................................... 39.9 41.6 40.1 38.6 39.0 44.7 43.6 40.4 39.9 40.6 43.0 39.9 38.6 40.4 39.9

Distillate Fuel Oil ............................................................. 126.8 176.9 172.5 161.2 145.5 140.1 130.0 133.6 123.8 129.0 136.2 137.5 161.2 133.6 137.5

Residual Fuel Oil ............................................................. 34.8 39.5 32.1 30.2 30.9 31.1 29.3 31.2 31.2 32.1 30.3 31.8 30.2 31.2 31.8

Other Oils (g) .................................................................. 61.9 59.0 48.3 49.1 55.8 54.1 49.9 52.2 61.3 59.1 49.9 51.3 49.1 52.2 51.3

Total Commercial Inventory ................................................ 1326.7 1457.7 1423.2 1343.3 1301.7 1271.5 1240.8 1211.3 1221.4 1284.4 1291.4 1264.6 1343.3 1211.3 1264.6

Crude Oil in SPR ................................................................ 635.0 656.0 642.2 638.1 637.8 621.3 621.3 601.3 601.3 601.3 601.3 591.7 638.1 601.3 591.7

(f) Petroleum products adjustment includes hydrogen/oxygenates/renewables/other hydrocarbons, motor gasoline blend components, and finished motor gasoline.

Table 4a. U.S. Petroleum and Other Liquids Supply, Consumption, and Inventories


2020 2021 2022 Year

(a) Includes lease condensate.

(b) Crude oil production from U.S. Federal leases in the Gulf of Mexico (GOM).

(c) Net imports equals gross imports minus gross exports.

(d) Crude oil adjustment balances supply and consumption and was previously referred to as "Unaccounted for Crude Oil."

(e) Renewables and oxygenate production includes pentanes plus, oxygenates (excluding fuel ethanol), and renewable fuels. Beginning in January 2021, renewable fuels includes biodiesel, renewable diesel,

renewable jet fuel, renewable heating oil, renewable naphtha and gasoline, and other renewable fuels. For December 2020 and prior, renewable fuels includes only biodiesel.


Petroleum Supply Annual , DOE/EIA-0340/2; and Weekly Petroleum Status Report , DOE/EIA-0208.



(g) For net imports and inventories “Other Oils" includes aviation gasoline blend components, finished aviation gasoline, kerosene, petrochemical feedstocks, special naphthas, lubricants, waxes, petroleum coke,

asphalt and road oil, still gas, and miscellaneous products; for consumption “Other Oils” also includes renewable fuels except fuel ethanol.


SPR: Strategic Petroleum Reserve

HC: Hydrocarbons



Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022

HGL Production

Natural Gas Processing Plants

Ethane .............................................................. 1.95 1.92 2.14 2.05 1.87 2.19 2.10 2.23 2.36 2.49 2.54 2.61 2.02 2.10 2.50

Propane ............................................................ 1.74 1.61 1.68 1.70 1.62 1.74 1.74 1.75 1.76 1.77 1.81 1.83 1.68 1.71 1.79

Butanes ............................................................ 0.92 0.86 0.90 0.89 0.85 0.92 0.93 0.93 0.93 0.94 0.96 0.97 0.89 0.91 0.95

Natural Gasoline (Pentanes Plus) .................... 0.57 0.57 0.62 0.58 0.53 0.61 0.63 0.59 0.58 0.61 0.64 0.62 0.58 0.59 0.61

Refinery and Blender Net Production

Ethane/Ethylene ............................................... 0.01 0.01 0.01 0.01 0.00 0.00 0.00 0.00 0.00 0.01 0.01 0.01 0.01 0.00 0.01

Propane ............................................................ 0.29 0.24 0.27 0.27 0.25 0.29 0.29 0.32 0.31 0.31 0.32 0.32 0.26 0.29 0.32

Propylene (refinery-grade) ............................... 0.25 0.26 0.26 0.29 0.27 0.31 0.27 0.28 0.28 0.28 0.28 0.28 0.26 0.28 0.28

Butanes/Butylenes ........................................... -0.08 0.18 0.13 -0.19 -0.09 0.24 0.20 -0.19 -0.08 0.26 0.19 -0.19 0.01 0.04 0.05

Renewable Fuels and Oxygenate Plant Net Production

Natural Gasoline (Pentanes Plus) .................... -0.02 -0.01 -0.02 -0.02 -0.02 -0.02 -0.02 -0.02 -0.02 -0.02 -0.02 -0.02 -0.02 -0.02 -0.02

HGL Net Imports

Ethane ................................................................. -0.30 -0.24 -0.26 -0.27 -0.35 -0.39 -0.39 -0.38 -0.43 -0.45 -0.45 -0.46 -0.27 -0.38 -0.45

Propane/Propylene .............................................. -1.08 -1.09 -1.06 -1.31 -1.11 -1.23 -1.21 -1.23 -1.13 -1.19 -1.23 -1.23 -1.14 -1.19 -1.20

Butanes/Butylenes .............................................. -0.30 -0.31 -0.34 -0.34 -0.35 -0.40 -0.44 -0.36 -0.39 -0.43 -0.44 -0.40 -0.32 -0.39 -0.41

Natural Gasoline (Pentanes Plus) ....................... -0.27 -0.19 -0.16 -0.14 -0.22 -0.21 -0.21 -0.18 -0.20 -0.18 -0.20 -0.18 -0.19 -0.20 -0.19

HGL Refinery and Blender Net Inputs

Butanes/Butylenes .............................................. 0.46 0.25 0.32 0.47 0.39 0.29 0.32 0.49 0.39 0.28 0.32 0.50 0.38 0.37 0.37

Natural Gasoline (Pentanes Plus) ....................... 0.15 0.10 0.15 0.13 0.14 0.14 0.17 0.16 0.17 0.18 0.18 0.18 0.13 0.15 0.18

HGL Consumption

Ethane/Ethylene .................................................. 1.71 1.68 1.67 1.81 1.54 1.83 1.73 1.88 2.01 2.04 2.09 2.13 1.72 1.75 2.07

Propane ............................................................... 1.14 0.58 0.61 0.97 1.09 0.65 0.63 1.00 1.13 0.57 0.58 1.02 0.82 0.84 0.82

Propylene (refinery-grade) .................................. 0.27 0.27 0.27 0.30 0.29 0.32 0.29 0.29 0.30 0.30 0.30 0.30 0.28 0.30 0.30



HGL Inventories (million barrels)

Ethane ................................................................. 53.2 50.6 62.5 74.8 65.8 67.4 63.4 63.4 55.7 55.2 54.7 57.7 60.3 65.0 55.9

Propane ............................................................... 60.8 75.8 100.3 69.9 39.3 53.2 69.7 52.5 33.3 61.1 89.1 78.9 69.9 52.5 78.9

Propylene (at refineries only) .............................. 1.5 1.5 1.5 1.5 1.1 1.2 1.6 1.7 1.6 1.8 2.0 1.9 1.5 1.7 1.9



Refinery and Blender Net Inputs

Crude OIl ............................................................. 15.77 13.16 14.02 13.90 13.81 15.65 15.39 15.06 15.09 16.48 17.12 16.14 14.21 14.98 16.21

Hydrocarbon Gas Liquids .................................... 0.61 0.35 0.47 0.60 0.53 0.43 0.49 0.65 0.55 0.47 0.51 0.69 0.51 0.52 0.55

Other Hydrocarbons/Oxygenates ....................... 1.12 0.95 1.11 1.08 1.05 1.19 1.18 1.15 1.13 1.20 1.21 1.18 1.06 1.14 1.18

Unfinished Oils .................................................... 0.06 0.22 0.45 0.19 -0.08 0.22 0.43 0.36 0.09 0.28 0.31 0.27 0.23 0.24 0.24

Motor Gasoline Blend Components .................... 0.41 0.49 0.85 0.46 0.71 0.92 0.75 0.26 0.56 0.81 0.65 0.30 0.55 0.66 0.58

Aviation Gasoline Blend Components ................ 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Total Refinery and Blender Net Inputs ................... 17.98 15.16 16.90 16.22 16.01 18.41 18.24 17.49 17.44 19.24 19.80 18.58 16.57 17.54 18.77

Refinery Processing Gain .................................. 1.02 0.82 0.93 0.92 0.84 0.97 1.00 1.04 1.05 1.09 1.14 1.13 0.92 0.96 1.10

Refinery and Blender Net Production

Hydrocarbon Gas Liquids .................................... 0.47 0.69 0.67 0.36 0.44 0.85 0.77 0.41 0.51 0.87 0.80 0.41 0.55 0.62 0.65

Finished Motor Gasoline ..................................... 9.31 7.53 9.14 8.98 8.74 9.82 9.67 9.55 9.32 9.87 10.03 9.79 8.74 9.45 9.75

Jet Fuel ................................................................ 1.63 0.62 0.83 1.00 1.10 1.32 1.38 1.36 1.50 1.61 1.70 1.57 1.02 1.29 1.60

Distillate Fuel ....................................................... 4.95 4.83 4.72 4.45 4.29 4.77 4.61 4.56 4.57 5.11 5.41 5.22 4.74 4.56 5.08

Residual Fuel ...................................................... 0.24 0.17 0.19 0.15 0.19 0.20 0.24 0.20 0.25 0.29 0.29 0.23 0.19 0.21 0.27

Other Oils (a) ....................................................... 2.41 2.14 2.28 2.19 2.09 2.42 2.57 2.44 2.33 2.57 2.71 2.49 2.26 2.38 2.53

Total Refinery and Blender Net Production ............ 19.00 15.98 17.84 17.14 16.86 19.38 19.24 18.53 18.49 20.33 20.94 19.71 17.49 18.51 19.87

Refinery Distillation Inputs ................................ 16.37 13.65 14.56 14.32 14.25 16.17 15.95 15.48 15.45 16.69 17.33 16.42 14.72 15.47 16.48

Refinery Operable Distillation Capacity ........... 18.98 18.75 18.55 18.39 18.11 18.13 18.13 18.13 18.13 18.13 18.13 18.13 18.66 18.12 18.13

Refinery Distillation Utilization Factor .............. 0.86 0.73 0.78 0.78 0.79 0.89 0.88 0.85 0.85 0.92 0.96 0.91 0.79 0.85 0.91

Table 4b. U.S. Hydrocarbon Gas Liquids (HGL) and Petroleum Refinery Balances (million barrels per day, except inventories and utilization factor)


2020 2021 2022 Year



(a) "Other Oils" includes aviation gasoline blend components, finished aviation gasoline, kerosene, petrochemical feedstocks, special naphthas, lubricants, waxes, petroleum coke, asphalt and road oil, still

gas, and miscellaneous products.





Petroleum Supply Annual , DOE/EIA-0340/2; Weekly Petroleum Status Report , DOE/EIA-0208.

Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022

Prices (cents per gallon)

Refiner Wholesale Price .......................... 153 104 137 133 180 217 230 207 197 204 198 182 133 210 195

Gasoline Regular Grade Retail Prices Including Taxes

PADD 1 ................................................... 236 191 211 212 252 287 302 286 266 273 272 255 214 283 267

PADD 2 ................................................... 226 179 207 202 247 288 302 275 251 271 263 245 204 279 258

PADD 3 ................................................... 210 162 186 183 228 267 281 259 245 252 246 230 187 261 244

PADD 4 ................................................... 247 200 233 221 247 311 357 307 279 290 287 268 226 307 281

PADD 5 ................................................... 311 258 283 278 312 366 388 355 349 359 344 347 284 357 350

U.S. Average ........................................ 241 194 218 215 256 297 314 291 273 285 278 264 218 291 275

Gasoline All Grades Including Taxes 251 203 227 224 265 306 324 303 286 298 292 278 227 301 289

End-of-period Inventories (million barrels)

Total Gasoline Inventories

PADD 1 ................................................... 71.0 73.1 61.8 68.5 65.1 69.9 56.0 59.1 65.1 68.1 63.2 68.7 68.5 59.1 68.7

PADD 2 ................................................... 60.2 52.7 46.2 50.9 50.7 50.6 47.9 49.7 53.3 52.2 50.2 50.7 50.9 49.7 50.7

PADD 3 ................................................... 85.8 91.3 80.4 84.0 81.9 81.6 77.6 84.7 85.2 88.9 83.4 89.4 84.0 84.7 89.4

PADD 4 ................................................... 9.2 7.7 7.6 8.7 8.6 6.2 7.1 7.9 7.9 7.9 7.5 8.1 8.7 7.9 8.1

PADD 5 ................................................... 35.6 29.7 31.5 31.4 31.4 29.0 30.1 31.3 30.1 29.5 29.4 31.8 31.4 31.3 31.8

U.S. Total ............................................. 261.8 254.5 227.6 243.4 237.6 237.2 218.7 232.8 241.6 246.5 233.8 248.7 243.4 232.8 248.7

Finished Gasoline Inventories

U.S. Total ............................................. 22.6 23.5 22.5 25.4 20.3 18.6 21.4 24.3 24.1 23.9 23.1 26.1 25.4 24.3 26.1

Gasoline Blending Components Inventories

U.S. Total ............................................. 239.2 231.0 205.0 218.0 217.4 218.6 197.3 208.5 217.5 222.6 210.6 222.7 218.0 208.5 222.7

Table 4c. U.S. Regional Motor Gasoline Prices and Inventories

U.S. Energy Information Administration | Short-Term Energy Outlook - September 20212020 2021 2022 Year

Historical data: Latest data available from Energy Information Administration databases supporting the following reports: Petroleum Marketing Monthly , DOE/EIA-0380;

Petroleum Supply Monthly , DOE/EIA-0109; Petroleum Supply Annual , DOE/EIA-0340/2; and Weekly Petroleum Status Report , DOE/EIA-0208.







Regions refer to Petroleum Administration for Defense Districts (PADD).

See “Petroleum for Administration Defense District” in EIA’s Energy Glossary (http://www.eia.doe.gov/glossary/index.html) for a list of States in each region.

Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022

Supply (billion cubic feet per day)

Total Marketed Production ............... 102.27 96.83 97.55 98.70 97.31 100.95 100.51 100.58 101.09 102.57 104.43 105.89 98.83 99.85 103.51

Alaska ........................................... 0.96 0.88 0.88 0.98 1.02 0.95 0.76 0.88 0.92 0.81 0.73 0.87 0.92 0.90 0.83

Federal GOM (a) .......................... 2.72 2.22 1.72 1.73 2.27 2.26 1.90 2.09 2.09 2.02 1.91 1.88 2.09 2.13 1.97

Lower 48 States (excl GOM) ....... 98.58 93.74 94.95 95.99 94.03 97.74 97.85 97.60 98.08 99.74 101.78 103.14 95.81 96.82 100.70

Total Dry Gas Production ............... 94.80 89.68 89.83 91.15 90.30 93.05 92.64 92.70 93.17 94.54 96.25 97.59 91.36 92.18 95.40

LNG Gross Imports ......................... 0.24 0.12 0.09 0.09 0.15 0.02 0.18 0.20 0.32 0.18 0.18 0.20 0.13 0.14 0.22

LNG Gross Exports ......................... 7.92 5.52 3.91 8.78 9.27 9.81 9.41 9.83 10.47 9.73 9.41 11.00 6.53 9.58 10.15

Pipeline Gross Imports .................... 7.60 6.08 6.39 7.27 8.68 6.80 6.80 6.85 7.39 6.36 6.38 6.72 6.84 7.28 6.71

Pipeline Gross Exports ................... 8.15 7.17 8.09 8.21 8.31 8.55 9.37 9.52 9.34 8.66 9.38 9.38 7.91 8.94 9.19

Supplemental Gaseous Fuels ........ 0.19 0.17 0.15 0.18 0.18 0.15 0.17 0.17 0.17 0.17 0.17 0.18 0.17 0.17 0.17

Net Inventory Withdrawals .............. 12.74 -12.24 -7.68 5.36 17.19 -9.12 -7.78 4.66 15.86 -10.79 -8.49 4.32 -0.46 1.18 0.17

Total Supply ....................................... 99.51 71.12 76.78 87.06 98.91 72.53 73.23 85.22 97.10 72.07 75.70 88.63 83.61 82.41 83.33

Balancing Item (b) .............................. -0.19 -0.28 0.05 -0.98 0.28 -0.42 1.25 -0.60 -0.33 -1.63 -0.15 -0.83 -0.35 0.13 -0.74

Total Primary Supply .......................... 99.31 70.84 76.83 86.08 99.20 72.12 74.48 84.62 96.77 70.44 75.55 87.80 83.25 82.54 82.60

Consumption (billion cubic feet per day)

Residential ...................................... 22.83 8.20 3.82 16.00 25.59 7.52 3.68 16.89 25.05 7.85 3.67 16.92 12.70 13.37 13.32

Commercial ..................................... 13.93 5.82 4.36 10.31 14.84 6.25 4.72 10.94 14.90 6.25 4.68 10.84 8.60 9.17 9.15

Industrial .......................................... 24.65 20.62 21.15 23.83 24.05 21.77 21.91 25.10 24.95 22.66 22.41 25.22 22.56 23.21 23.81

Electric Power (c) ............................ 29.55 29.05 40.10 28.19 26.65 29.14 36.67 23.87 23.61 26.19 37.05 26.61 31.74 29.09 28.40

Lease and Plant Fuel ...................... 5.17 4.90 4.93 4.99 4.92 5.10 5.08 5.09 5.11 5.19 5.28 5.35 5.00 5.05 5.23

Pipeline and Distribution Use .......... 3.02 2.15 2.33 2.61 3.01 2.19 2.27 2.59 2.98 2.13 2.29 2.69 2.53 2.51 2.52

Vehicle Use ..................................... 0.16 0.10 0.13 0.13 0.14 0.15 0.15 0.15 0.16 0.16 0.16 0.16 0.13 0.15 0.16

Total Consumption ............................. 99.31 70.84 76.83 86.08 99.20 72.12 74.48 84.62 96.77 70.44 75.55 87.80 83.25 82.54 82.60

End-of-period Inventories (billion cubic feet)

Working Gas Inventory ................... 2,029 3,133 3,840 3,341 1,801 2,583 3,299 2,870 1,442 2,424 3,205 2,808 3,341 2,870 2,808

East Region (d) ............................ 385 655 890 763 313 515 808 658 174 452 682 498 763 658 498

Midwest Region (d) ...................... 471 747 1,053 918 395 630 970 823 278 537 894 790 918 823 790

South Central Region (d) ............. 857 1,221 1,313 1,155 760 991 1,030 979 698 960 1,039 970 1,155 979 970

Mountain Region (d) .................... 92 177 235 195 113 175 196 146 93 148 218 201 195 146 201

Pacific Region (d) ......................... 200 308 318 282 197 246 264 233 168 296 342 318 282 233 318

Alaska ........................................... 23 25 31 28 23 27 31 31 31 31 31 31 28 31 31

LNG: liquefied natural gas.

Table 5a. U.S. Natural Gas Supply, Consumption, and Inventories


2020 2021 2022 Year

(a) Marketed production from U.S. Federal leases in the Gulf of Mexico.

(b) The balancing item represents the difference between the sum of the components of natural gas supply and the sum of components of natural gas demand.

(c) Natural gas used for electricity generation and (a limited amount of) useful thermal output by electric utilities and independent power producers.

(d) For a list of States in each inventory region refer to Weekly Natural Gas Storage Report, Notes and Definitions (http://ir.eia.gov/ngs/notes.html) .




Historical data: Latest data available from Energy Information Administration databases supporting the following reports: Natural Gas Monthly , DOE/EIA-0130; and Electric Power Monthly ,



Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022

Wholesale/Spot

Henry Hub Spot Price ......... 1.98 1.77 2.07 2.63 3.70 3.06 4.15 4.16 4.28 3.41 3.38 3.34 2.11 3.77 3.60

Residential Retail

New England ....................... 13.77 14.50 18.28 14.64 14.78 16.18 18.91 14.61 14.17 14.98 17.59 13.47 14.47 15.19 14.31

Middle Atlantic ..................... 10.77 11.85 17.85 11.77 10.41 13.43 17.55 11.83 10.90 13.07 17.49 11.43 11.76 11.67 11.83

E. N. Central ....................... 6.99 9.50 18.15 8.02 7.41 12.72 20.39 10.83 9.58 12.03 17.21 8.69 8.39 9.74 10.09

W. N. Central ...................... 6.85 9.89 17.26 8.66 7.59 11.57 18.56 10.46 9.15 11.92 17.67 9.50 8.48 9.46 10.12

S. Atlantic ........................... 12.12 15.52 24.15 14.20 12.10 18.04 24.95 14.08 12.51 17.41 23.21 12.84 14.23 14.35 14.07

E. S. Central ....................... 9.69 13.34 20.85 10.63 9.53 14.93 22.78 14.41 11.49 16.02 22.58 13.58 11.15 11.90 13.51

W. S. Central ...................... 8.52 14.22 20.83 11.67 9.32 15.97 21.53 12.65 9.89 15.48 20.85 11.69 11.40 12.11 12.16

Mountain ............................. 7.55 9.37 12.60 8.15 7.90 10.60 14.46 9.36 8.88 10.60 14.16 8.89 8.43 9.15 9.55

Pacific ................................. 13.41 14.47 14.50 13.70 14.28 15.11 15.57 14.43 14.61 15.22 15.76 14.55 13.82 14.62 14.84

U.S. Average ................... 9.46 11.89 17.65 10.60 9.79 13.87 18.86 12.09 10.97 13.59 17.94 11.01 10.83 11.73 11.85

Commercial Retail

New England ....................... 9.93 10.40 10.99 10.06 10.38 11.15 11.95 11.26 11.55 11.43 10.80 10.39 10.16 10.93 11.08

Middle Atlantic ..................... 7.91 7.00 6.78 7.53 7.87 7.96 7.47 8.18 8.65 8.35 7.69 8.02 7.50 7.93 8.28

E. N. Central ....................... 5.75 6.73 8.79 6.21 6.12 8.67 10.66 8.29 7.99 8.66 9.25 6.88 6.28 7.50 7.82

W. N. Central ...................... 5.43 6.53 8.12 6.55 6.31 7.65 9.58 8.21 8.12 8.40 9.30 7.26 6.14 7.32 7.97

S. Atlantic ........................... 8.51 9.21 9.55 8.88 8.79 9.83 10.58 9.80 9.56 10.15 10.08 8.80 8.87 9.49 9.49

E. S. Central ....................... 8.38 9.20 10.10 8.69 8.43 9.86 10.96 9.96 9.40 10.24 10.49 9.12 8.78 9.38 9.55

W. S. Central ...................... 5.99 7.18 8.13 7.46 7.01 8.32 9.47 8.92 8.13 8.50 8.58 7.61 6.92 8.09 8.12

Mountain ............................. 6.09 6.85 7.42 6.45 6.50 7.78 8.92 7.98 7.81 8.13 8.80 7.51 6.46 7.40 7.87

Pacific ................................. 9.58 9.30 9.59 9.70 10.50 10.42 10.86 10.24 10.17 9.94 10.17 9.62 9.57 10.46 9.95

U.S. Average ................... 7.13 7.63 8.49 7.53 7.55 8.84 9.66 8.88 8.73 9.03 9.13 8.03 7.48 8.39 8.61

Industrial Retail

New England ....................... 8.15 7.41 6.16 7.67 8.58 8.09 7.31 8.64 9.25 8.51 7.22 8.00 7.54 8.26 8.40

Middle Atlantic ..................... 7.43 6.76 7.00 7.61 7.70 7.38 7.62 8.32 8.90 8.38 7.94 8.16 7.28 7.83 8.49

E. N. Central ....................... 4.84 5.10 4.15 5.10 5.39 8.11 7.26 6.76 7.01 6.44 5.99 5.77 4.86 6.45 6.42

W. N. Central ...................... 3.97 3.30 3.15 4.13 5.20 4.28 4.98 5.91 6.24 5.20 4.79 5.11 3.68 5.14 5.39

S. Atlantic ........................... 4.15 3.70 3.72 4.56 5.05 4.69 5.65 6.22 6.43 5.38 5.05 5.15 4.06 5.40 5.55

E. S. Central ....................... 3.92 3.24 3.23 4.04 4.64 4.20 5.24 5.92 6.10 5.10 4.64 4.84 3.65 4.98 5.21

W. S. Central ...................... 2.19 1.92 2.19 2.89 5.75 3.21 4.29 4.39 4.45 3.68 3.59 3.49 2.31 4.37 3.80

Mountain ............................. 4.40 4.59 4.67 4.91 5.00 5.52 6.33 6.55 6.64 6.26 6.22 5.89 4.64 5.76 6.27

Pacific ................................. 7.46 6.28 6.18 7.23 8.30 7.23 7.61 7.85 7.98 7.34 7.32 7.19 6.86 7.77 7.47

U.S. Average ................... 3.52 2.85 2.88 3.77 5.72 4.06 4.91 5.38 5.69 4.60 4.33 4.52 3.29 5.05 4.81

Table 5b. U.S. Regional Natural Gas Prices (dollars per thousand cubic feet)


2020 2021 2022 Year

Historical data: Latest data available from Energy Information Administration databases supporting the Natural Gas Monthly , DOE/EIA-0130.

Natural gas Henry Hub spot price from Reuter's News Service (http://www.reuters.com).







Regions refer to U.S. Census divisions.

See "Census division" in EIA’s Energy Glossary (http://www.eia.doe.gov/glossary/index.html) for a list of States in each region.

Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022

Supply (million short tons)

Production .................................................. 149.2 116.2 135.9 134.1 140.3 152.3 151.2 157.3 163.9 158.0 165.3 160.7 535.3 601.1 647.9

Appalachia ............................................... 39.8 29.5 33.9 35.5 40.8 38.1 39.1 41.6 45.3 46.3 43.0 43.8 138.7 159.7 178.4

Interior ..................................................... 25.8 20.0 23.2 21.8 25.0 25.3 25.3 26.9 29.1 28.9 29.9 29.6 90.7 102.4 117.5

Western ................................................... 83.6 66.7 78.8 76.8 74.5 88.9 86.8 88.8 89.5 82.8 92.4 87.3 305.9 339.1 352.0

Primary Inventory Withdrawals ................... 0.5 1.3 2.0 -0.9 0.3 2.1 2.3 -1.9 -1.1 -1.8 -0.6 -5.0 2.8 2.8 -8.5

Imports ....................................................... 1.3 1.1 1.3 1.3 1.1 1.5 1.4 1.2 0.9 0.9 1.1 1.1 5.1 5.2 4.1

Exports ....................................................... 20.0 14.8 15.3 19.1 20.7 22.1 22.1 25.5 28.1 19.9 20.3 25.7 69.1 90.5 94.0

Metallurgical Coal .................................... 11.7 9.0 10.2 11.3 10.3 11.7 14.2 14.0 15.3 11.4 12.7 13.8 42.1 50.2 53.2

Steam Coal ............................................. 8.3 5.8 5.1 7.8 10.4 10.4 8.0 11.5 12.8 8.5 7.6 11.9 27.0 40.3 40.8

Total Primary Supply ..................................... 131.0 103.9 123.9 115.4 121.0 133.8 132.8 131.1 135.6 137.2 145.5 131.1 474.2 518.7 549.5

Secondary Inventory Withdrawals ............... -16.6 -5.0 21.5 -3.3 21.3 -0.8 33.7 16.4 11.4 -7.9 9.2 -3.2 -3.5 70.6 9.5

Waste Coal (a) ........................................... 1.9 1.5 2.0 2.3 2.0 2.0 2.0 2.0 1.8 1.8 1.8 1.8 7.7 8.0 7.4

Total Supply .................................................. 116.3 100.3 147.3 114.4 144.3 135.0 168.4 149.5 148.9 131.1 156.6 129.8 478.4 597.3 566.4

Consumption (million short tons)

Coke Plants ................................................ 4.3 3.5 3.2 3.5 4.4 5.1 4.2 4.6 5.6 4.6 4.3 4.7 14.4 18.3 19.1

Electric Power Sector (b) ............................ 97.9 87.2 139.3 112.1 128.1 113.8 157.3 137.7 136.0 119.5 145.4 117.9 436.5 536.9 518.7

Retail and Other Industry ............................ 7.4 5.7 6.1 7.2 6.8 6.9 6.9 7.2 7.4 7.0 7.0 7.2 26.4 27.8 28.6

Residential and Commercial .................... 0.3 0.1 0.1 0.2 0.3 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.8 0.9 0.8

Other Industrial ........................................ 7.1 5.6 5.9 7.0 6.6 6.7 6.7 7.0 7.1 6.9 6.8 7.0 25.6 27.0 27.8

Total Consumption ....................................... 109.5 96.4 148.6 122.8 139.4 125.7 168.4 149.5 148.9 131.1 156.6 129.8 477.3 583.0 566.4

Discrepancy (c) 6.8 3.9 -1.2 -8.4 5.0 9.3 0.0 0.0 0.0 0.0 0.0 0.0 1.1 14.3 0.0

End-of-period Inventories (million short tons)

Primary Inventories (d) ............................... 30.8 29.5 27.5 28.5 28.1 26.1 23.8 25.7 26.8 28.6 29.2 34.2 28.5 25.7 34.2

Secondary Inventories ................................ 150.6 155.6 134.2 137.5 116.1 117.0 83.3 66.9 55.5 63.4 54.2 57.4 137.5 66.9 57.4

Electric Power Sector .............................. 145.2 150.4 129.1 132.7 111.8 111.2 77.5 61.3 50.1 57.7 48.4 51.8 132.7 61.3 51.8

Retail and General Industry ..................... 3.0 3.0 2.9 2.8 2.6 3.6 3.6 3.4 3.7 3.5 3.5 3.3 2.8 3.4 3.3

Coke Plants ............................................. 2.1 2.0 2.0 1.7 1.5 2.0 2.1 2.0 1.7 2.1 2.2 2.1 1.7 2.0 2.1

Commercial & Institutional …………… .... 0.2 0.2 0.2 0.3 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.3 0.2 0.2

Coal Market Indicators

Coal Miner Productivity

(Tons per hour) ........................................ 6.37 6.37 6.37 6.37 6.32 6.32 6.32 6.32 6.30 6.30 6.30 6.30 6.37 6.32 6.30

Total Raw Steel Production

(Million short tons per day) ....................... 0.268 0.174 0.197 0.224 0.246 0.258 0.275 0.329 0.329 0.291 0.288 0.302 0.216 0.277 0.302

Cost of Coal to Electric Utilities

(Dollars per million Btu) ........................... 1.93 1.91 1.93 1.92 1.91 1.92 1.98 1.99 2.02 2.02 1.99 1.96 1.92 1.95 2.00

Table 6. U.S. Coal Supply, Consumption, and Inventories


2020 2021 2022 Year


Historical data: Latest data available from Energy Information Administration databases supporting the following reports: Quarterly Coal Report , DOE/EIA-0121; and Electric Power Monthly ,



(a) Waste coal includes waste coal and cloal slurry reprocessed into briquettes.

(b) Coal used for electricity generation and (a limited amount of) useful thermal output by electric utilities and independent power producers.

(c) The discrepancy reflects an unaccounted-for shipper and receiver reporting difference, assumed to be zero in the forecast period.

(d) Primary stocks are held at the mines and distribution points.



Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022

Electricity Supply (billion kilowatthours)

Electricity Generation ........................ 966 933 1,148 962 989 984 1,157 975 986 1,002 1,158 988 4,009 4,104 4,133

Electric Power Sector (a) ................. 925 896 1,109 923 952 948 1,116 936 947 964 1,116 949 3,853 3,952 3,976

Industrial Sector (b) ......................... 38 34 36 36 34 33 37 36 35 35 37 36 143 139 143

Commercial Sector (b) .................... 3 3 4 3 3 3 4 3 3 3 4 3 13 13 14

Net Imports ...................................... 10 11 15 12 11 12 14 10 11 12 14 11 47 46 49

Total Supply ....................................... 976 944 1,163 973 999 996 1,170 985 997 1,014 1,172 999 4,056 4,150 4,182

Losses and Unaccounted for (c) ...... 53 67 71 63 53 65 63 55 45 68 58 55 254 236 226

Electricity Consumption (billion kilowatthours unless noted)

Retail Sales ........................................ 887 844 1,057 876 914 898 1,072 896 918 912 1,078 909 3,664 3,780 3,817

Residential Sector .......................... 340 334 453 334 379 328 444 338 365 327 441 344 1,462 1,489 1,477

Commercial Sector ......................... 314 293 360 309 305 322 367 315 312 328 370 318 1,276 1,308 1,328

Industrial Sector .............................. 231 216 242 231 229 247 260 241 239 255 266 245 920 977 1,006

Transportation Sector ..................... 2 1 2 2 2 1 2 2 2 2 2 2 7 6 6

Direct Use (d) .................................... 36 33 35 34 33 32 36 35 34 33 36 35 138 135 139

Total Consumption ........................... 923 877 1,092 910 947 930 1,107 930 952 946 1,114 944 3,802 3,915 3,956

Average residential electricity

usage per customer (kWh) ................ 2,496 2,451 3,326 2,451 2,744 2,378 3,213 2,447 2,613 2,341 3,151 2,459 10,723 10,782 10,563

End-of-period Fuel Inventories Held by Electric Power Sector

Coal (mmst) ....................................... 145.2 150.4 129.1 132.7 111.8 111.2 77.5 61.3 50.1 57.7 48.4 51.8 132.7 61.3 51.8

Residual Fuel (mmb) ......................... 8.3 8.5 8.2 8.3 8.0 7.5 7.8 8.2 7.8 7.8 7.8 8.2 8.3 8.2 8.2

Distillate Fuel (mmb) .......................... 16.5 16.5 17.0 16.8 15.9 15.3 15.4 15.7 15.6 15.5 15.5 15.8 16.8 15.7 15.8

Prices

Power Generation Fuel Costs (dollars per million Btu)

Coal ................................................ 1.93 1.91 1.93 1.92 1.91 1.92 1.98 1.99 2.02 2.02 1.99 1.96 1.92 1.95 2.00

Natural Gas .................................... 2.39 2.08 2.26 2.87 7.26 3.27 4.16 4.42 4.76 3.53 3.42 3.56 2.39 4.69 3.75

Residual Fuel Oil ............................ 12.15 6.65 8.85 8.90 11.28 12.99 13.03 13.01 13.03 13.33 12.32 11.90 9.15 12.72 12.70

Distillate Fuel Oil ............................. 13.27 8.39 10.37 10.54 13.59 15.40 15.85 16.52 16.15 16.07 15.16 15.17 10.73 14.93 15.59

Retail Prices (cents per kilowatthour)

Residential Sector .......................... 12.90 13.24 13.35 13.25 13.09 13.78 13.89 13.76 13.68 14.14 13.97 13.73 13.20 13.63 13.88

Commercial Sector ......................... 10.33 10.63 10.97 10.62 11.11 11.07 11.52 11.09 11.41 11.21 11.44 10.96 10.65 11.21 11.26

Industrial Sector .............................. 6.38 6.63 7.08 6.53 7.15 6.90 7.26 6.58 6.96 6.84 7.16 6.57 6.66 6.97 6.89

Wholesale Electricity Prices (dollars per megawatthour)

ERCOT North hub .......................... 23.41 24.03 34.12 26.41 616.34 39.74 41.67 24.17 29.70 24.96 30.27 25.83 26.99 180.48 27.69

CAISO SP15 zone .......................... 28.64 19.21 61.94 42.80 44.74 36.90 54.28 17.49 18.03 17.56 19.92 17.00 38.15 38.35 18.13

ISO-NE Internal hub ....................... 24.61 20.25 27.20 34.03 55.26 33.67 53.32 52.61 54.31 53.80 56.46 49.52 26.52 48.71 53.52

NYISO Hudson Valley zone ............ 21.82 18.13 24.38 27.05 44.74 31.85 48.44 45.95 49.03 46.74 49.05 43.16 22.85 42.74 46.99

PJM Western hub ........................... 22.47 20.79 28.24 26.44 35.09 33.71 45.02 35.49 37.47 33.35 37.52 32.55 24.49 37.33 35.23

Midcontinent ISO Illinois hub .......... 24.43 23.00 29.35 24.94 44.97 33.82 43.47 33.38 34.75 32.10 34.84 30.49 25.43 38.91 33.04

SPP ISO South hub ........................ 20.06 19.54 26.27 24.34 250.31 30.86 41.15 26.35 27.51 26.93 30.40 25.04 22.55 87.17 27.47

SERC index, Into Southern ............ 23.58 18.23 23.47 25.21 41.10 32.93 39.92 32.01 33.71 30.62 32.33 28.99 22.62 36.49 31.41

FRCC index, Florida Reliability ....... 26.24 18.53 23.75 25.39 27.73 32.17 40.43 36.35 37.11 32.90 33.46 31.70 23.48 34.17 33.79

Northwest index, Mid-Columbia ..... 22.77 14.49 33.56 31.00 34.56 51.51 69.08 15.91 19.36 16.81 19.09 16.94 25.46 42.76 18.05

Southwest index, Palo Verde ......... 22.07 19.60 80.81 36.10 41.72 46.57 57.82 13.09 15.96 16.09 17.32 14.99 39.64 39.80 16.09

(b) Generation supplied by power plants with capacity of at least 1 megawatt operated by businesses in the commercial and industrial sectors, primarily for onsite use.

Table 7a. U.S. Electricity Industry Overview


2020 2021 2022 Year



kWh = kilowatthours. Btu = British thermal units.


(a) Generation supplied by power plants with capacity of at least 1 megawatt operated by electric utilities and independent power producers.

(3) PJM ISO Western Hub wholesale electricity prices: PJM Data Miner website



(c) Includes transmission and distribution losses, data collection time-frame differences, and estimation error.

(d) Direct Use represents commercial and industrial facility use of onsite net electricity generation; and electrical sales or transfers to adjacent or colocated facilities

for which revenue information is not available. See Table 7.6 of the EIA Monthly Energy Review .

Historical data sources:

(1) Electricity supply, consumption, fuel costs, and retail electricity prices: Latest data available from U.S. Energy Information Administration databases

supporting the following reports: Electric Power Monthly, DOE/EIA-0226; and Electric Power Annual, DOE/EIA-0348

(2) Wholesale electricity prices (except for PJM RTO price): S&P Global Market Intelligence, SNL Energy Data

(3) PJM ISO Western hub wholesale electricity prices: PJM Data Miner website.

Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022

Residential Sector

New England ............... 11.7 10.9 14.6 11.0 12.9 10.8 14.0 11.1 12.4 10.4 13.3 10.9 48.2 48.9 46.9

Middle Atlantic .............. 32.2 30.6 43.5 30.9 36.1 30.3 42.2 31.6 37.0 30.3 40.1 31.7 137.1 140.3 139.1

E. N. Central ................ 46.4 43.7 56.5 43.4 50.2 43.1 55.0 44.7 48.3 42.1 52.8 45.3 190.0 193.1 188.4

W. N. Central ............... 27.6 23.7 30.0 24.5 29.9 23.7 30.1 26.1 31.9 24.9 31.6 27.8 105.8 109.8 116.2

S. Atlantic ..................... 84.3 86.3 114.7 85.3 95.2 85.1 113.2 85.7 91.4 84.8 112.4 86.9 370.6 379.3 375.6

E. S. Central ................. 29.0 26.0 37.2 26.6 33.8 25.6 36.5 27.4 32.5 26.1 37.0 27.8 118.8 123.3 123.4

W. S. Central ............... 48.8 52.9 76.4 48.5 56.8 49.5 73.1 49.1 50.9 51.2 77.5 51.1 226.5 228.6 230.8

Mountain ...................... 22.5 25.7 36.2 24.0 23.7 26.9 34.5 23.8 23.0 25.3 34.4 24.1 108.4 108.9 106.8

Pacific contiguous ........ 36.7 33.2 43.0 38.6 39.0 32.2 43.8 37.0 36.9 31.1 40.4 36.9 151.5 152.0 145.3

AK and HI ..................... 1.3 1.1 1.2 1.3 1.3 1.1 1.2 1.3 1.2 1.1 1.2 1.3 4.9 4.9 4.8

Total .......................... 340.3 334.1 453.4 334.1 378.9 328.4 443.7 337.9 365.4 327.4 440.7 343.9 1,462.0 1,488.9 1,477.3

Commercial Sector

New England ............... 12.3 10.6 13.2 11.4 11.7 11.7 13.2 11.4 11.7 11.6 13.1 11.4 47.5 48.1 47.7

Middle Atlantic .............. 35.9 31.0 38.9 33.2 34.6 33.3 39.9 34.4 36.0 34.4 40.3 35.2 138.9 142.2 145.9

E. N. Central ................ 43.1 38.3 47.3 41.0 41.7 42.2 47.5 42.0 42.8 42.8 47.4 42.3 169.7 173.4 175.3

W. N. Central ............... 24.7 21.6 26.3 23.4 24.0 23.7 26.5 24.1 25.0 24.4 27.2 24.6 96.0 98.3 101.3

S. Atlantic ..................... 72.0 70.0 85.7 72.4 70.8 77.3 87.0 72.7 72.0 78.8 87.9 73.4 300.2 307.8 312.2

E. S. Central ................. 20.7 19.4 25.3 20.4 20.9 21.7 25.4 20.8 21.3 22.5 25.7 20.9 85.8 88.7 90.4

W. S. Central ............... 44.3 44.6 55.0 45.4 42.4 50.2 56.8 47.3 43.3 52.1 58.4 47.9 189.4 196.6 201.7

Mountain ...................... 22.4 22.1 27.4 22.8 21.9 24.8 28.1 23.2 22.5 24.7 28.3 23.4 94.7 98.0 98.9


AK and HI ..................... 1.4 1.2 1.3 1.3 1.3 1.3 1.4 1.4 1.3 1.4 1.4 1.4 5.2 5.3 5.5

Total .......................... 313.7 292.7 360.3 308.9 304.6 321.6 366.6 315.0 311.9 328.5 369.7 317.9 1,275.7 1,307.9 1,328.1

Industrial Sector

New England ............... 3.7 3.5 3.9 3.7 3.8 4.0 4.2 3.8 3.9 4.0 4.2 3.8 14.8 15.7 15.9

Middle Atlantic .............. 18.0 16.2 18.6 17.6 17.6 17.9 19.6 18.1 18.3 18.5 20.0 18.5 70.4 73.3 75.4

E. N. Central ................ 44.0 37.7 44.5 42.5 44.8 46.6 48.2 44.4 47.6 48.2 49.4 45.3 168.7 183.9 190.5

W. N. Central ............... 21.7 20.3 23.2 22.1 23.0 24.2 25.6 23.7 24.9 25.7 26.5 24.2 87.3 96.5 101.3

S. Atlantic ..................... 32.8 31.0 34.2 33.6 33.4 35.9 36.2 34.5 34.6 36.8 36.8 35.1 131.7 140.0 143.4

E. S. Central ................. 23.3 21.4 23.4 22.9 23.8 25.0 25.6 24.0 24.9 25.6 25.8 24.1 91.1 98.4 100.4

W. S. Central ............... 46.6 44.9 47.9 48.7 44.1 49.7 52.2 51.7 46.0 51.9 53.9 53.2 188.1 197.6 205.1

Mountain ...................... 20.1 20.3 22.6 19.9 19.2 21.6 23.8 20.1 19.3 21.7 24.1 20.4 82.9 84.7 85.5


AK and HI ..................... 1.2 1.0 1.2 1.2 1.1 1.1 1.2 1.2 1.1 1.2 1.2 1.2 4.5 4.6 4.6

Total .......................... 230.7 216.0 241.6 231.2 228.8 246.9 259.9 241.0 239.2 255.1 265.8 245.4 919.5 976.6 1,005.5

Total All Sectors (a)

New England ............... 27.8 25.1 31.9 26.3 28.5 26.7 31.6 26.4 28.1 26.1 30.7 26.1 111.0 113.2 111.0

Middle Atlantic .............. 86.9 78.5 101.8 82.5 89.2 82.3 102.5 84.9 92.2 84.1 101.2 86.1 349.7 358.9 363.6

E. N. Central ................ 133.7 119.7 148.4 127.0 136.9 132.0 150.8 131.3 138.8 133.2 149.7 133.0 528.8 550.9 554.7

W. N. Central ............... 74.0 65.7 79.5 70.0 77.0 71.6 82.1 73.8 81.8 75.1 85.2 76.7 289.2 304.6 318.8

S. Atlantic ..................... 189.5 187.6 235.0 191.6 199.7 198.6 236.7 193.2 198.3 200.8 237.4 195.7 803.7 828.1 832.2

E. S. Central ................. 73.0 66.8 85.9 69.9 78.5 72.4 87.4 72.2 78.7 74.2 88.6 72.8 295.7 310.4 314.2

W. S. Central ............... 139.8 142.4 179.4 142.7 143.3 149.5 182.2 148.1 140.3 155.3 189.9 152.3 604.2 623.0 637.8

Mountain ...................... 65.0 68.2 86.3 66.7 64.8 73.3 86.4 67.2 64.8 71.8 86.9 67.9 286.2 291.7 291.4


AK and HI ..................... 3.8 3.4 3.6 3.8 3.6 3.6 3.7 3.9 3.7 3.6 3.7 3.9 14.6 14.8 15.0

Total .......................... 886.6 844.3 1,056.9 875.9 914.0 898.4 1,071.8 895.5 918.2 912.5 1,077.8 908.8 3,663.7 3,779.7 3,817.2

Table 7b. U.S. Regional Electricity Retail Sales (billion kilowatthours)


2020 2021 2022 Year


Historical data: Latest data available from Energy Information Administration databases supporting the following reports: Electric Power Monthly , DOE/EIA-0226; and Electric



(a) Total retail sales to all sectors includes residential, commercial, industrial, and transportation sector sales.




Retail Sales represents total retail electricity sales by electric utilities and power marketers.


Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022

Residential Sector

New England .............. 21.76 21.32 20.95 20.80 21.38 20.82 21.86 22.54 23.75 23.39 24.59 25.10 21.20 21.65 24.22

Middle Atlantic ............. 15.47 15.96 16.18 15.98 15.62 16.28 16.92 16.90 16.41 16.87 17.35 17.07 15.92 16.44 16.93

E. N. Central ............... 13.14 13.75 13.33 13.75 13.38 14.40 13.90 14.17 13.92 14.87 14.27 14.34 13.48 13.94 14.33

W. N. Central .............. 10.98 12.59 12.88 11.46 10.88 12.76 13.61 11.73 10.62 12.15 12.80 11.19 11.99 12.24 11.68

S. Atlantic .................... 11.79 11.80 12.05 11.83 11.66 12.31 12.43 12.32 12.37 12.90 12.83 12.37 11.88 12.19 12.63

E. S. Central ............... 11.24 11.56 11.28 11.41 11.18 12.22 11.85 11.85 11.67 12.46 11.92 11.85 11.36 11.74 11.95

W. S. Central .............. 11.04 11.42 11.29 11.37 11.85 11.72 12.02 12.28 12.63 11.62 11.52 11.73 11.29 11.97 11.83

Mountain ..................... 11.42 12.08 12.19 11.64 11.53 12.09 12.23 11.76 11.67 12.12 12.05 11.50 11.88 11.94 11.86

Pacific ......................... 15.69 16.18 17.77 16.79 16.76 18.15 18.02 16.82 17.02 18.94 18.57 16.91 16.67 17.43 17.84

U.S. Average ........... 12.90 13.24 13.35 13.25 13.09 13.78 13.89 13.76 13.68 14.14 13.97 13.73 13.20 13.63 13.88

Commercial Sector

New England .............. 16.24 15.67 15.98 15.67 16.28 15.75 17.03 16.85 17.58 17.00 18.26 17.84 15.90 16.49 17.69

Middle Atlantic ............. 11.69 12.53 13.21 12.41 12.48 13.34 13.95 13.15 13.11 13.90 14.30 13.39 12.47 13.26 13.69

E. N. Central ............... 9.95 10.37 10.19 10.29 10.40 10.69 10.60 10.79 10.79 10.93 10.67 10.76 10.19 10.62 10.78

W. N. Central .............. 9.07 10.12 10.33 9.12 9.10 10.19 11.23 9.61 8.86 9.45 10.27 9.00 9.66 10.06 9.41

S. Atlantic .................... 9.23 9.02 9.09 9.20 9.29 9.18 9.42 9.74 9.81 9.45 9.46 9.59 9.13 9.41 9.57

E. S. Central ............... 10.75 10.83 10.60 10.67 10.96 11.23 11.20 11.20 11.32 11.38 11.28 11.25 10.70 11.15 11.31

W. S. Central .............. 7.84 7.87 7.89 7.98 11.28 8.85 8.30 7.91 10.98 8.88 8.48 8.15 7.90 8.99 9.04

Mountain ..................... 9.00 9.82 10.09 9.31 9.11 9.76 10.22 9.39 9.08 9.59 9.84 9.00 9.58 9.66 9.41

Pacific ......................... 13.50 14.79 17.20 15.05 14.53 16.00 18.16 15.71 14.88 15.98 17.35 14.85 15.18 16.17 15.80

U.S. Average ........... 10.33 10.63 10.97 10.62 11.11 11.07 11.52 11.09 11.41 11.21 11.44 10.96 10.65 11.21 11.26

Industrial Sector

New England .............. 12.29 12.22 12.41 12.12 13.49 12.78 13.31 12.73 14.07 13.23 13.71 13.03 12.26 13.08 13.51

Middle Atlantic ............. 6.36 6.35 6.41 6.28 6.50 6.55 6.62 6.34 6.41 6.46 6.39 6.15 6.35 6.51 6.35

E. N. Central ............... 6.51 6.78 6.75 6.62 6.92 6.93 7.00 6.80 6.95 6.95 6.96 6.80 6.66 6.91 6.92

W. N. Central .............. 6.94 7.32 7.89 6.62 6.97 7.30 8.05 6.73 6.90 7.35 8.08 6.81 7.20 7.28 7.30

S. Atlantic .................... 5.98 6.09 6.50 6.09 6.24 6.30 6.81 6.27 6.36 6.30 6.70 6.20 6.17 6.41 6.39

E. S. Central ............... 5.45 5.51 5.70 5.52 5.75 5.87 5.95 5.61 5.72 5.83 5.86 5.56 5.54 5.80 5.75

W. S. Central .............. 5.05 4.98 5.21 5.03 7.60 5.45 5.26 4.88 6.56 5.15 5.01 4.77 5.07 5.73 5.33

Mountain ..................... 5.73 6.15 6.91 5.94 6.23 6.62 7.06 5.87 6.15 6.51 6.93 5.92 6.21 6.48 6.41

Pacific ......................... 8.97 10.33 12.38 10.95 9.64 10.70 12.33 10.93 9.72 10.77 12.41 11.33 10.71 10.99 11.14

U.S. Average ........... 6.38 6.63 7.08 6.53 7.15 6.90 7.26 6.58 6.96 6.84 7.16 6.57 6.66 6.97 6.89

All Sectors (a)

New England .............. 18.02 17.61 17.79 17.27 18.19 17.34 18.65 18.61 19.78 18.93 20.35 20.13 17.68 18.22 19.82

Middle Atlantic ............. 11.98 12.58 13.23 12.42 12.56 12.94 13.76 13.09 13.10 13.33 13.93 13.19 12.58 13.11 13.41

E. N. Central ............... 9.92 10.47 10.36 10.24 10.35 10.57 10.65 10.59 10.56 10.73 10.71 10.63 10.24 10.54 10.66

W. N. Central .............. 9.15 10.15 10.58 9.15 9.16 10.07 11.11 9.43 8.95 9.62 10.53 9.10 9.77 9.97 9.57

S. Atlantic .................... 9.80 9.82 10.16 9.82 9.91 10.00 10.46 10.26 10.38 10.33 10.63 10.22 9.91 10.17 10.40

E. S. Central ............... 9.25 9.41 9.56 9.26 9.48 9.72 9.94 9.59 9.69 9.84 9.97 9.60 9.38 9.69 9.78

W. S. Central .............. 8.03 8.28 8.63 8.12 10.37 8.67 8.92 8.30 10.13 8.53 8.73 8.17 8.29 9.05 8.86

Mountain ..................... 8.83 9.58 10.14 9.14 9.15 9.69 10.15 9.18 9.12 9.55 9.91 8.97 9.48 9.59 9.43

Pacific ......................... 13.41 14.30 16.41 14.92 14.50 15.53 16.82 15.15 14.68 15.75 16.68 14.91 14.82 15.55 15.54

U.S. Average ........... 10.29 10.63 11.11 10.54 10.94 10.92 11.47 10.88 11.15 11.04 11.42 10.82 10.66 11.07 11.12

Table 7c. U.S. Regional Retail Electricity Prices (Cents per Kilowatthour)


2020 2021 2022 Year


Historical data: Latest data available from Energy Information Administration databases supporting the following reports: Electric Power Monthly , DOE/EIA-0226; and Electric



(a) Volume-weighted average of retail prices to residential, commercial, industrial, and transportation sectors.






Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022

United States

Natural Gas ................................... 354.7 342.6 474.2 340.7 318.2 345.4 436.5 291.3 285.5 313.3 444.3 327.3 1,512.2 1,391.4 1,370.4

Coal .............................................. 170.3 151.2 248.2 198.6 230.3 203.8 283.0 248.0 246.2 218.5 260.3 212.5 768.2 965.0 937.5

Nuclear ......................................... 204.1 190.7 204.1 191.0 198.5 185.2 204.1 185.8 187.1 185.1 197.1 184.2 789.9 773.6 753.6

Renewable Energy Sources: ......... 190.1 206.5 176.9 187.0 198.0 208.2 187.7 204.2 220.3 240.4 209.5 217.9 760.6 798.1 888.1

Conventional Hydropower 75.0 81.3 70.6 63.0 69.3 67.2 57.7 55.2 66.4 78.3 63.4 58.0 289.9 249.5 266.0

Wind .......................................... 87.4 87.1 67.5 94.7 96.3 95.2 79.5 111.3 113.7 105.9 87.5 118.2 336.7 382.4 425.4

Solar (a) .................................... 16.7 27.3 27.6 18.5 21.4 35.2 35.7 24.0 28.2 45.1 44.9 29.5 90.1 116.3 147.8

Biomass ..................................... 7.1 6.7 7.0 6.7 7.0 6.6 10.4 9.5 8.0 7.8 9.3 8.1 27.5 33.5 33.1

Geothermal ................................ 3.9 4.2 4.2 4.2 3.9 4.0 4.3 4.2 4.0 3.3 4.3 4.2 16.5 16.3 15.7

Pumped Storage Hydropower ....... -1.0 -1.2 -2.0 -1.2 -1.1 -1.0 -2.5 -1.1 -0.9 -0.9 -2.3 -1.0 -5.3 -5.6 -5.1

Petroleum (b) ............................... 4.0 3.9 4.5 4.0 5.2 3.5 5.1 5.1 6.5 4.9 5.3 5.2 16.5 19.1 21.8

Other Gases ................................. 1.0 0.4 0.8 0.9 0.7 0.8 0.7 0.7 0.6 0.7 0.6 0.8 3.1 2.9 2.7

Other Nonrenewable Fuels (c) ...... 1.9 1.8 1.9 1.9 1.9 1.8 1.7 1.9 1.8 1.8 1.7 1.9 7.5 7.2 7.2

Total Generation ........................... 925.2 896.1 1,108.5 922.9 951.8 947.8 1,116.2 935.9 947.2 963.9 1,116.5 948.8 3,852.8 3,951.6 3,976.3

New England (ISO-NE)

Natural Gas ................................... 10.8 10.0 16.1 10.8 12.1 11.0 15.7 11.6 10.9 11.4 16.0 10.9 47.7 50.3 49.3

Coal .............................................. 0.1 0.0 0.0 0.1 0.5 0.0 0.7 0.7 0.5 0.1 0.3 0.3 0.2 1.9 1.2

Nuclear ......................................... 7.3 4.9 7.3 6.1 7.1 7.1 7.3 5.6 7.0 6.2 7.2 7.2 25.6 27.0 27.7

Conventional hydropower .............. 2.2 2.1 1.8 1.7 1.9 1.8 1.2 1.8 2.0 2.3 1.3 1.8 7.8 6.7 7.4

Nonhydro renewables (d) ............. 2.6 2.7 2.4 2.6 2.8 2.9 3.7 3.7 3.5 3.5 3.9 3.6 10.3 13.1 14.5

Other energy sources (e) ............. 0.3 0.3 0.4 0.4 0.4 0.3 1.5 1.4 2.2 1.9 1.4 1.0 1.4 3.6 6.5

Total generation ............................ 23.2 20.1 28.0 21.7 24.7 23.0 30.1 24.8 26.1 25.4 30.2 24.8 92.9 102.6 106.6

Net energy for load (f) .................. 27.9 25.2 32.3 27.6 29.4 26.9 32.1 28.2 29.4 27.6 32.1 28.3 113.0 116.6 117.4

New York (NYISO)

Natural Gas ................................... 12.4 11.4 20.6 12.8 12.8 14.0 18.9 13.8 14.6 13.1 19.4 13.5 57.1 59.5 60.5

Coal .............................................. 0.1 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.1 0.0 0.0

Nuclear ......................................... 10.7 9.2 9.0 9.6 9.3 7.7 7.3 6.8 6.5 7.0 6.7 7.0 38.5 31.0 27.3






Mid-Atlantic (PJM)

Natural Gas ................................... 78.4 69.9 97.6 69.9 72.5 70.9 87.2 61.0 73.9 69.4 96.1 73.0 315.8 291.5 312.4

Coal .............................................. 33.7 29.7 46.8 38.1 50.5 39.8 51.9 50.1 56.2 45.1 46.1 44.8 148.3 192.3 192.2

Nuclear ......................................... 68.9 67.1 70.9 68.9 68.4 64.6 71.4 62.3 59.0 59.2 62.9 57.7 275.7 266.7 238.8



Other energy sources (e) ............. 0.6 0.5 0.4 0.7 1.0 0.5 -0.1 0.7 1.2 0.6 0.0 0.9 2.2 2.2 2.7



Southeast (SERC)

Natural Gas ................................... 61.9 59.1 74.7 58.5 57.6 57.2 67.1 49.2 54.2 54.9 74.3 58.2 254.2 231.1 241.7

Coal .............................................. 23.8 22.1 44.4 28.0 36.3 33.7 48.0 40.3 39.8 38.7 45.5 36.4 118.3 158.2 160.3

Nuclear ......................................... 53.0 50.5 54.1 52.5 53.8 50.9 55.5 52.0 52.5 55.2 58.5 54.9 210.1 212.2 221.0



Other energy sources (e) ............. -0.1 -0.3 -0.6 -0.2 0.0 -0.2 -0.9 -0.2 -0.3 -0.4 -0.9 -0.2 -1.1 -1.4 -1.7



Florida (FRCC)

Natural Gas ................................... 40.0 45.7 52.8 41.0 34.5 43.7 48.8 34.9 30.4 43.2 49.4 37.5 179.5 162.0 160.5

Coal .............................................. 2.1 3.5 5.7 4.6 4.7 5.3 6.0 5.5 4.1 6.0 5.5 5.1 15.9 21.5 20.8

Nuclear ......................................... 7.3 7.6 7.6 7.0 7.8 7.2 7.8 6.9 7.9 7.3 8.1 7.1 29.4 29.7 30.4






(f) Regional generation from generating units operated by electric power sector, plus energy receipts from minus energy deliveries to U.S. balancing authorities outside region.

Table 7d part 1. U.S. Regional Electricity Generation, Electric Power Sector (billion kilowatthours), continues on Table 7d part 2


2020 2021 2022 Year

(a) Solar generation from large-scale power plants with more than 1 megawatt of capacity. Excludes generation from small-scale solar photovoltaic systems.

(b) Residual fuel oil, distillate fuel oil, petroleum coke, and other petroleum liquids.

(c) Batteries, chemicals, hydrogen, pitch, purchased steam, sulfur, nonrenewable waste, and miscellaneous technologies.

(d) Wind, large-scale solar, biomass, and geothermal

(e) Pumped storage hydroelectric, petroleum, other gases, batteries, and other nonrenewable fuels. See notes (b) and (c).



Data reflect generation supplied by power plants with a combined capacity of at least 1 megawatt operated by electric utilities and independent power producers.

Historical data: Latest data available from U.S. Energy Information Administration databases supporting the following reports: Electric Power Monthly , DOE/EIA-0226; and Electric Power

Annual , DOE/EIA-0348.

Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022

Midwest (MISO)

Natural Gas ................................... 43.9 43.2 53.4 37.7 34.5 40.2 45.6 28.1 29.4 38.2 53.7 40.0 178.3 148.4 161.2

Coal .............................................. 51.0 41.1 68.5 57.8 69.7 60.1 80.7 70.0 69.8 61.5 70.9 56.2 218.4 280.5 258.4

Nuclear ......................................... 26.6 22.9 24.4 21.2 23.6 22.6 24.3 23.5 23.8 22.2 23.7 23.0 95.1 94.0 92.6






Central (Southwest Power Pool)

Natural Gas ................................... 17.5 16.3 24.2 13.7 12.4 14.5 18.6 7.3 7.6 14.4 21.6 13.3 71.6 52.9 56.9

Coal .............................................. 17.0 15.7 26.7 19.8 21.8 19.8 30.1 24.9 25.4 18.5 28.2 20.6 79.2 96.6 92.8

Nuclear ......................................... 4.4 4.4 4.2 3.8 4.1 2.8 4.3 4.4 4.3 4.3 4.1 2.5 16.8 15.6 15.2



Other energy sources (e) ............. 0.1 0.1 0.1 0.2 0.3 0.1 -0.1 0.1 -0.1 -0.1 -0.1 0.2 0.5 0.5 -0.1



Texas (ERCOT)

Natural Gas ................................... 37.2 42.1 59.3 36.0 33.0 40.0 52.2 27.8 22.6 28.9 44.7 23.9 174.6 153.0 120.0

Coal .............................................. 13.1 15.8 20.3 17.9 16.3 18.5 24.0 21.5 17.0 20.7 23.4 18.5 67.2 80.3 79.6

Nuclear ......................................... 10.4 9.7 11.0 10.3 10.5 9.8 10.3 9.5 10.7 10.0 10.6 10.8 41.4 40.1 42.0






Northwest

Natural Gas ................................... 23.7 17.1 27.3 21.6 20.9 20.1 31.1 23.2 18.9 14.3 24.4 24.6 89.6 95.3 82.3

Coal .............................................. 22.3 16.1 24.5 23.2 22.5 19.0 29.9 24.7 24.4 18.6 29.4 21.6 86.1 96.1 93.9

Nuclear ......................................... 2.4 2.0 2.4 2.5 2.5 1.2 2.5 2.4 2.4 2.4 2.4 2.4 9.4 8.7 9.7



Other energy sources (e) ............. 0.2 0.2 0.1 0.2 0.2 0.2 0.0 0.1 0.1 -0.1 0.0 0.1 0.6 0.4 0.1



Southwest

Natural Gas ................................... 11.8 14.7 20.4 14.8 11.0 15.8 21.5 11.1 6.4 8.9 16.9 9.8 61.7 59.4 42.0

Coal .............................................. 5.3 5.3 8.8 6.6 5.9 5.6 9.3 7.6 6.9 7.1 8.7 5.8 25.9 28.4 28.5

Nuclear ......................................... 8.3 7.6 8.7 7.0 8.5 7.1 8.6 7.7 8.4 7.5 8.6 7.5 31.6 31.8 32.1



Other energy sources (e) ............. 0.0 0.1 0.1 0.0 0.0 0.1 0.0 0.0 0.0 0.0 0.0 0.0 0.2 0.1 -0.1



California

Natural Gas ................................... 16.7 12.6 27.0 23.6 16.6 17.4 29.2 22.6 15.8 15.9 27.2 21.9 79.9 85.8 80.9

Coal .............................................. 1.4 1.2 2.1 2.0 1.8 1.4 1.9 2.2 1.8 1.5 1.8 2.8 6.7 7.2 7.9

Nuclear ......................................... 4.8 4.9 4.5 2.1 2.9 4.2 4.9 4.7 4.6 3.8 4.4 4.0 16.3 16.7 16.7



Other energy sources (e) ............. 0.0 0.1 0.1 0.1 0.0 -0.1 -0.1 0.1 0.0 -0.3 -0.1 0.1 0.2 -0.2 -0.4



(f) Regional generation from generating units operated by electric power sector, plus energy receipts from minus energy deliveries to U.S. balancing authorities outside region.

Table 7d part 2. U.S. Regional Electricity Generation, Electric Power Sector (billion kilowatthours), continued from Table 7d part 1


2020 2021 2022 Year


Data reflect generation supplied by power plants with a combined capacity of at least 1 megawatt operated by electric utilities and independent power producers.

Historical data: Latest data available from U.S. Energy Information Administration databases supporting the following reports: Electric Power Monthly , DOE/EIA-0226; and Electric Power

Annual , DOE/EIA-0348.

(a) Large-scale solar generation from power plants with more than 1 megawatt of capacity. Excludes generation from small-scale solar photovoltaic systems.

(b) Residual fuel oil, distillate fuel oil, petroleum coke, and other petroleum liquids.

(c) Batteries, chemicals, hydrogen, pitch, purchased steam, sulfur, nonrenewable waste, and miscellaneous technologies.

(d) Wind, large-scale solar, biomass, and geothermal

(e) Pumped storage hydroelectric, petroleum, other gases, batteries, and other nonrenewable fuels. See notes (b) and (c).


Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022

Electric Power Sector

Geothermal .......................................... 0.035 0.037 0.037 0.038 0.035 0.035 0.038 0.037 0.035 0.029 0.038 0.037 0.147 0.145 0.140

Hydroelectric Power (a) ........................ 0.668 0.724 0.629 0.561 0.617 0.604 0.599 0.559 0.691 0.694 0.597 0.556 2.581 2.379 2.538

Solar (b) ................................................ 0.152 0.248 0.252 0.168 0.195 0.320 0.325 0.218 0.257 0.411 0.409 0.268 0.820 1.059 1.346

Waste Biomass (c) ................................ 0.063 0.058 0.059 0.059 0.059 0.057 0.082 0.079 0.062 0.056 0.078 0.075 0.238 0.276 0.271

Wood Biomass ..................................... 0.049 0.043 0.048 0.046 0.050 0.045 0.079 0.068 0.061 0.065 0.065 0.049 0.185 0.242 0.241

Wind ..................................................... 0.796 0.793 0.615 0.862 0.877 0.867 0.724 1.013 1.035 0.965 0.797 1.076 3.065 3.482 3.872

Subtotal ............................................. 1.761 1.904 1.639 1.733 1.833 1.928 1.847 1.975 2.143 2.220 1.985 2.061 7.037 7.583 8.408

Industrial Sector

Biofuel Losses and Co-products (d) ...... 0.197 0.135 0.179 0.188 0.169 0.188 0.191 0.190 0.186 0.192 0.197 0.196 0.698 0.738 0.770

Geothermal .......................................... 0.001 0.001 0.001 0.001 0.001 0.001 0.001 0.001 0.001 0.001 0.001 0.001 0.004 0.004 0.004


Solar (b) ............................................... 0.007 0.010 0.010 0.007 0.007 0.011 0.011 0.008 0.008 0.012 0.012 0.009 0.033 0.037 0.041

Waste Biomass (c) ................................ 0.041 0.039 0.036 0.041 0.041 0.039 0.038 0.040 0.040 0.039 0.038 0.040 0.156 0.158 0.157

Wood Biomass ..................................... 0.349 0.340 0.336 0.352 0.338 0.344 0.354 0.358 0.349 0.347 0.359 0.362 1.376 1.394 1.416

Subtotal ............................................. 0.594 0.520 0.558 0.588 0.555 0.579 0.590 0.596 0.582 0.586 0.602 0.605 2.261 2.321 2.375

Commercial Sector

Geothermal .......................................... 0.006 0.006 0.006 0.006 0.006 0.006 0.006 0.006 0.006 0.006 0.006 0.006 0.024 0.024 0.024

Solar (b) ............................................... 0.025 0.037 0.037 0.025 0.029 0.043 0.044 0.031 0.035 0.051 0.051 0.035 0.123 0.146 0.172

Waste Biomass (c) ................................ 0.010 0.008 0.009 0.009 0.009 0.008 0.009 0.009 0.009 0.008 0.009 0.009 0.036 0.035 0.035

Wood Biomass ..................................... 0.021 0.021 0.021 0.021 0.020 0.020 0.021 0.021 0.020 0.020 0.021 0.021 0.083 0.082 0.082

Subtotal ............................................. 0.068 0.077 0.078 0.067 0.070 0.085 0.086 0.073 0.076 0.092 0.094 0.078 0.290 0.314 0.340

Residential Sector

Geothermal .......................................... 0.010 0.010 0.010 0.010 0.010 0.010 0.010 0.010 0.010 0.010 0.010 0.010 0.040 0.040 0.040

Solar (e) ................................................. 0.058 0.086 0.086 0.061 0.066 0.101 0.105 0.074 0.081 0.123 0.124 0.086 0.291 0.346 0.413

Wood Biomass ..................................... 0.114 0.114 0.115 0.115 0.112 0.113 0.115 0.115 0.112 0.113 0.115 0.115 0.458 0.455 0.455

Subtotal ............................................. 0.181 0.210 0.211 0.186 0.188 0.225 0.230 0.199 0.203 0.246 0.249 0.211 0.788 0.841 0.908

Transportation Sector

Biomass-based Diesel (f) ...................... 0.062 0.066 0.073 0.075 0.056 0.072 0.075 0.084 0.081 0.083 0.087 0.094 0.275 0.287 0.345

Ethanol (f) .............................................. 0.258 0.222 0.266 0.259 0.244 0.283 0.284 0.274 0.259 0.285 0.290 0.283 1.006 1.085 1.117

Subtotal ............................................. 0.320 0.288 0.340 0.334 0.300 0.354 0.360 0.358 0.340 0.368 0.377 0.376 1.281 1.372 1.462

All Sectors Total

Biomass-based Diesel (f) ...................... 0.062 0.066 0.073 0.075 0.056 0.072 0.075 0.084 0.081 0.083 0.087 0.094 0.275 0.287 0.345

Biofuel Losses and Co-products (d) ...... 0.197 0.135 0.179 0.188 0.169 0.188 0.191 0.190 0.186 0.192 0.197 0.196 0.698 0.738 0.770

Ethanol (f) .............................................. 0.268 0.231 0.277 0.269 0.253 0.293 0.295 0.285 0.269 0.296 0.301 0.293 1.045 1.127 1.160

Geothermal .......................................... 0.052 0.054 0.054 0.055 0.051 0.052 0.055 0.054 0.052 0.046 0.055 0.054 0.214 0.213 0.208


Solar (b)(e) ........................................... 0.238 0.374 0.377 0.257 0.292 0.470 0.485 0.330 0.381 0.596 0.596 0.398 1.246 1.577 1.971

Waste Biomass (c) ................................ 0.113 0.105 0.104 0.108 0.108 0.104 0.129 0.128 0.111 0.103 0.125 0.124 0.430 0.469 0.463

Wood Biomass ..................................... 0.532 0.517 0.519 0.533 0.520 0.523 0.568 0.562 0.542 0.546 0.560 0.546 2.101 2.173 2.195

Wind ..................................................... 0.796 0.793 0.615 0.862 0.877 0.867 0.724 1.013 1.035 0.965 0.797 1.076 3.065 3.482 3.872

Total Consumption ................................. 2.925 3.000 2.826 2.907 2.946 3.171 3.113 3.200 3.343 3.512 3.307 3.331 11.657 12.430 13.493

(a) Conventional hydroelectric power only. Hydroelectricity generated by pumped storage is not included in renewable energy.

(b) Solar consumption in the electric power, commercial, and industrial sectors includes energy produced from large scale (>1 MW) solar thermal and photovoltaic generators and small-scale (<1 MW) distributed solar photovoltaic systems.

(c) Municipal solid waste from biogenic sources, landfill gas, sludge waste, agricultural byproducts, and other biomass.

(d) Losses and co-products from the production of fuel ethanol and biomass-based diesel

(e) Solar consumption in the residential sector includes energy from small-scale (<1 MW) solar photovoltaic systems. Also includes solar heating consumption in all sectors.



Table 8a. U.S. Renewable Energy Consumption (Quadrillion Btu)


2020 2021 2022 Year

(f) Fuel ethanol and biomass-based diesel consumption in the transportation sector includes production, stock change, and imports less exports. Some biomass-based diesel may be consumed in

the residential sector in heating oil.



Historical data: Latest data available from EIA databases supporting the following reports: Electric Power Monthly , DOE/EIA-0226 and Renewable Energy Annual , DOE/EIA-0603; Petroleum


Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022

Renewable Energy Electric Generating Capacity (megawatts, end of period)

Electric Power Sector (a)

Biomass .............................................. 6,601 6,599 6,550 6,549 6,539 6,395 6,396 6,439 6,442 6,444 6,444 6,444 6,549 6,439 6,444

Waste .............................................. 3,928 3,926 3,853 3,851 3,842 3,840 3,842 3,885 3,888 3,890 3,890 3,890 3,851 3,885 3,890

Wood ............................................... 2,673 2,673 2,697 2,697 2,697 2,554 2,554 2,554 2,554 2,554 2,554 2,554 2,697 2,554 2,554

Conventional Hydroelectric ................ 79,488 79,482 79,629 79,631 79,632 79,702 79,706 79,722 79,755 79,765 79,806 79,809 79,631 79,722 79,809

Geothermal ......................................... 2,505 2,523 2,523 2,523 2,523 2,523 2,523 2,565 2,565 2,565 2,565 2,565 2,523 2,565 2,565

Large-Scale Solar (b) ......................... 39,060 41,153 42,954 47,574 50,244 52,116 56,380 63,492 65,554 69,711 72,187 79,837 47,574 63,492 79,837

Wind ................................................... 106,123 107,617 109,144 118,112 120,998 124,339 127,810 135,696 136,400 137,954 138,664 141,972 118,112 135,696 141,972

Other Sectors (c)

Biomass .............................................. 6,430 6,431 6,427 6,438 6,417 6,420 6,405 6,405 6,405 6,405 6,397 6,397 6,438 6,405 6,397

Waste .............................................. 781 782 778 789 787 790 790 790 790 790 790 790 789 790 790

Wood ............................................... 5,649 5,649 5,649 5,649 5,630 5,630 5,615 5,615 5,615 5,615 5,607 5,607 5,649 5,615 5,607

Conventional Hydroelectric ................ 288 288 288 288 288 288 284 286 286 286 286 286 288 286 286

Large-Scale Solar (b) ......................... 442 455 461 467 471 471 496 539 539 539 541 542 467 539 542

Small-Scale Solar (d) ......................... 24,355 25,255 26,264 27,724 28,888 30,385 31,964 33,541 35,065 36,479 37,881 39,261 27,724 33,541 39,261

Residential Sector ........................... 15,071 15,689 16,373 17,238 18,076 19,144 20,256 21,370 22,412 23,367 24,290 25,174 17,238 21,370 25,174

Commercial Sector .......................... 7,425 7,642 7,910 8,430 8,725 9,104 9,508 9,908 10,325 10,723 11,137 11,567 8,430 9,908 11,567

Industrial Sector ............................... 1,859 1,924 1,981 2,056 2,088 2,138 2,201 2,264 2,328 2,390 2,454 2,519 2,056 2,264 2,519

Wind ................................................... 113 339 348 348 348 348 348 348 348 348 348 348 348 348 348

Renewable Electricity Generation (billion kilowatthours)

Electric Power Sector (a)

Biomass .............................................. 7.1 6.7 7.0 6.7 7.0 6.6 10.4 9.5 8.0 7.8 9.3 8.1 27.5 33.5 33.1

Waste .............................................. 4.1 4.0 4.0 3.9 4.0 3.9 5.5 5.3 4.2 3.8 5.3 5.1 16.1 18.7 18.4

Wood ............................................... 3.0 2.7 3.0 2.7 3.1 2.7 4.8 4.2 3.8 4.0 4.0 3.0 11.4 14.9 14.8

Conventional Hydroelectric ................ 75.0 81.3 70.6 63.0 69.3 67.2 57.7 55.2 66.4 78.3 63.4 58.0 289.9 249.5 266.0

Geothermal ....................................... 3.9 4.2 4.2 4.2 3.9 4.0 4.3 4.2 4.0 3.3 4.3 4.2 16.5 16.3 15.7

Large-Scale Solar (b) ......................... 16.7 27.3 27.6 18.5 21.4 35.2 35.7 24.0 28.2 45.1 44.9 29.5 90.1 116.3 147.8

Wind .................................................. 87.4 87.1 67.5 94.7 96.3 95.2 79.5 111.3 113.7 105.9 87.5 118.2 336.7 382.4 425.4

Other Sectors (c)

Biomass .............................................. 7.4 7.1 7.0 7.1 7.0 6.8 7.0 7.1 7.0 6.8 7.0 7.1 28.6 27.9 27.9

Waste .............................................. 0.7 0.7 0.7 0.7 0.7 0.6 0.7 0.7 0.7 0.6 0.7 0.7 2.7 2.7 2.7

Wood ............................................... 6.7 6.4 6.4 6.4 6.3 6.2 6.4 6.4 6.3 6.2 6.4 6.4 25.8 25.3 25.3

Conventional Hydroelectric ................ 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 1.2 1.2 1.2

Large-Scale Solar (b) ......................... 0.2 0.2 0.2 0.2 0.2 0.3 0.3 0.2 0.2 0.3 0.3 0.2 0.8 0.9 0.9

Small-Scale Solar (d) ......................... 8.4 12.4 12.3 8.7 9.8 14.8 15.1 10.6 11.9 17.9 18.1 12.5 41.7 50.2 60.5

Residential Sector .......................... 5.0 7.5 7.5 5.4 5.9 9.1 9.4 6.6 7.4 11.3 11.4 7.9 25.4 31.0 38.0

Commercial Sector ......................... 2.7 3.8 3.8 2.6 3.1 4.5 4.6 3.2 3.7 5.3 5.4 3.7 12.9 15.3 18.1

Industrial Sector .............................. 0.7 1.0 1.0 0.7 0.8 1.1 1.2 0.8 0.9 1.3 1.3 0.9 3.5 3.9 4.4

Wind .................................................. 0.1 0.1 0.2 0.4 0.3 0.3 0.2 0.2 0.2 0.2 0.2 0.2 0.8 1.0 0.9

(a) Power plants larger than or equal to one megawatt in size that are operated by electric utilities or independent power producers.

(b) Solar thermal and photovoltaic generating units at power plants larger than or equal to 1 megawatt.

(d) Solar photovoltaic systems smaller than one megawatt.

Historical data: Latest data available from EIA databases supporting the Electric Power Monthly, DOE/EIA-0226.


Table 8b. U.S. Renewable Electricity Generation and Capacity


2020 2021 2022 Year

(c) Businesses or individual households not primarily engaged in electric power production for sale to the public, whose generating capacity is at least one megawatt (except for small-scale solar

photovoltaic data, which consists of systems smaller than 1 megawatt).





Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022

Macroeconomic

Real Gross Domestic Product

(billion chained 2012 dollars - SAAR) ............ 18,952 17,258 18,561 18,768 19,056 19,358 19,643 19,914 20,149 20,290 20,417 20,533 18,385 19,493 20,347

Real Personal Consumption Expend.


Real Private Fixed Investment


Business Inventory Change

(billion chained 2012 dollars - SAAR) ............ -21 -290 15 57 -94 -169 29 79 185 193 185 172 -60 -39 183

Real Government Expenditures


Real Exports of Goods & Services


Real Imports of Goods & Services


Real Disposable Personal Income


Non-Farm Employment

(millions) ....................................................... 151.9 133.7 140.9 142.6 143.4 145.0 147.6 149.5 151.0 152.2 153.0 153.6 142.3 146.4 152.5

Civilian Unemployment Rate

(percent) ...................................................... 3.8 13.1 8.8 6.8 6.2 5.9 5.2 4.7 4.3 4.0 3.8 3.6 8.1 5.5 3.9

Housing Starts

(millions - SAAR) ........................................... 1.49 1.09 1.44 1.58 1.60 1.59 1.56 1.55 1.49 1.44 1.41 1.39 1.40 1.57 1.43

Industrial Production Indices (Index, 2017=100)

Total Industrial Production ............................... 100.0 87.1 95.5 97.4 98.3 99.8 101.2 102.1 103.5 104.4 105.0 105.6 95.0 100.3 104.6

Manufacturing .............................................. 97.6 84.2 94.2 96.7 97.3 98.6 100.4 101.7 103.4 104.5 105.2 105.9 93.2 99.5 104.7

Food ........................................................ 101.8 93.8 98.0 100.1 101.2 100.7 100.6 101.0 101.4 101.7 102.1 102.6 98.4 100.9 102.0

Paper ....................................................... 99.5 91.5 90.7 94.9 93.9 95.0 95.5 96.2 96.7 97.2 97.7 97.9 94.2 95.2 97.4

Petroleum and Coal Products .................... 98.0 77.3 84.0 86.7 90.5 96.2 97.6 99.3 100.2 100.9 101.5 101.5 86.5 95.9 101.0

Chemicals ................................................. 95.0 89.9 92.5 94.7 91.7 98.9 101.2 102.6 104.0 105.3 106.0 106.3 93.0 98.6 105.4

Nonmetallic Mineral Products ................... 99.7 88.1 94.6 98.4 97.4 95.1 95.7 96.2 96.5 96.6 96.7 96.8 95.2 96.1 96.6

Primary Metals .......................................... 95.9 72.9 83.3 90.3 92.4 96.8 99.2 99.5 100.7 101.8 102.2 102.0 85.6 97.0 101.7

Coal-weighted Manufacturing (a) .................. 97.1 86.7 93.0 96.6 94.2 97.2 98.7 99.6 100.8 101.6 102.2 102.5 93.3 97.4 101.8

Distillate-weighted Manufacturing (a) ............ 97.0 84.4 92.0 95.7 94.6 97.2 98.7 99.5 100.4 101.2 101.6 101.7 92.3 97.5 101.2

Electricity-weighted Manufacturing (a) .......... 97.1 83.4 91.6 95.4 94.5 97.8 99.7 100.7 102.0 103.2 103.9 104.2 91.9 98.2 103.3

Natural Gas-weighted Manufacturing (a) ....... 95.5 84.1 89.7 93.7 90.5 96.4 98.3 99.3 100.5 101.6 102.2 102.4 90.8 96.1 101.7

Price Indexes

Consumer Price Index (all urban consumers)

(index, 1982-1984=1.00) ............................... 2.59 2.56 2.59 2.61 2.63 2.69 2.73 2.74 2.75 2.76 2.76 2.78 2.59 2.70 2.76

Producer Price Index: All Commodities

(index, 1982=1.00) ........................................ 1.97 1.88 1.94 1.99 2.11 2.23 2.26 2.24 2.23 2.22 2.21 2.20 1.94 2.21 2.21

Producer Price Index: Petroleum

(index, 1982=1.00) ........................................ 1.71 1.05 1.47 1.50 1.89 2.19 2.26 2.15 2.05 2.07 2.02 1.92 1.43 2.12 2.02

GDP Implicit Price Deflator

(index, 2012=100) ......................................... 113.4 113.0 114.0 114.6 115.8 117.5 118.7 119.6 120.1 120.6 121.0 121.6 113.7 117.9 120.8

Miscellaneous

Vehicle Miles Traveled (b)

(million miles/day) .......................................... 7,764 6,868 8,262 8,009 7,679 8,940 9,175 8,807 8,268 9,279 9,355 9,026 7,728 8,655 8,985

Air Travel Capacity

(Available ton-miles/day, thousands) ............. 630 362 478 537 537 607 675 671 647 688 702 671 502 623 677

Aircraft Utilization

(Revenue ton-miles/day, thousands) .............. 328 151 208 238 245 324 355 380 402 449 448 407 231 327 426

Airline Ticket Price Index

(index, 1982-1984=100) ................................ 250.8 203.7 200.6 215.1 198.4 243.3 228.8 224.9 227.3 250.7 244.3 255.9 217.5 223.9 244.6

Raw Steel Production

(million short tons per day) ............................. 0.268 0.174 0.197 0.224 0.246 0.258 0.275 0.329 0.329 0.291 0.288 0.302 0.216 0.277 0.302

Carbon Dioxide (CO2) Emissions (million metric tons)

Petroleum ........................................................ 553 442 518 522 516 557 576 570 559 576 591 590 2,035 2,219 2,316

Natural Gas ..................................................... 490 349 383 429 485 355 371 422 473 347 377 438 1,651 1,633 1,634

Coal ................................................................ 201 177 271 224 255 231 308 274 274 241 289 241 873 1,067 1,044

Total Energy (c) ............................................... 1,247 971 1,174 1,178 1,259 1,146 1,257 1,269 1,308 1,167 1,259 1,272 4,571 4,931 5,005

SAAR = Seasonally-adjusted annual rate

Table 9a. U.S. Macroeconomic Indicators and CO2 Emissions


2020 2021 2022 Year

Historical data: Latest data available from U.S. Department of Commerce, Bureau of Economic Analysis; Federal Reserve System, Statistical release G17; Federal Highway Administration; and Federal


Forecasts: EIA Short-Term Integrated Forecasting System. U.S. macroeconomic forecasts are based on the IHS Markit model of the U.S. Economy.

(a) Fuel share weights of individual sector indices based on EIA Manufacturing Energy Consumption Survey .

(b) Total highway travel includes gasoline and diesel fuel vehicles.

(c) Includes electric power sector use of geothermal energy and non-biomass waste.




Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022

Real Gross State Product (Billion $2012)

New England ................ 982 891 959 971 986 1,001 1,015 1,029 1,041 1,047 1,054 1,059 951 1,008 1,050

Middle Atlantic .............. 2,745 2,459 2,641 2,667 2,708 2,758 2,800 2,841 2,880 2,904 2,926 2,943 2,628 2,777 2,913

E. N. Central ................ 2,476 2,241 2,432 2,454 2,494 2,518 2,551 2,585 2,612 2,631 2,646 2,659 2,401 2,537 2,637

W. N. Central ............... 1,175 1,072 1,156 1,172 1,190 1,206 1,221 1,235 1,247 1,253 1,260 1,265 1,144 1,213 1,256

S. Atlantic ..................... 3,352 3,080 3,302 3,334 3,387 3,432 3,480 3,526 3,566 3,588 3,607 3,625 3,267 3,456 3,596

E. S. Central ................ 819 734 801 812 825 835 845 855 863 869 873 878 791 840 871

W. S. Central ............... 2,293 2,101 2,243 2,279 2,304 2,344 2,374 2,407 2,438 2,457 2,477 2,495 2,229 2,357 2,467

Mountain ...................... 1,270 1,165 1,252 1,266 1,290 1,311 1,331 1,348 1,364 1,372 1,379 1,388 1,238 1,320 1,376

Pacific .......................... 3,729 3,399 3,645 3,676 3,731 3,811 3,881 3,941 3,992 4,020 4,044 4,070 3,612 3,841 4,031

Industrial Output, Manufacturing (Index, Year 2017=100)

New England ................ 96.1 82.6 91.6 94.6 95.0 90.9 92.4 93.5 95.0 95.8 96.3 96.8 91.3 93.0 96.0

Middle Atlantic .............. 95.0 79.2 89.9 92.5 92.9 89.2 90.8 92.3 93.9 94.9 95.5 96.0 89.2 91.3 95.1

E. N. Central ................ 95.9 79.0 91.8 94.4 95.0 97.5 99.1 100.6 102.6 104.0 105.0 105.9 90.3 98.1 104.4

W. N. Central ............... 98.0 86.0 94.7 97.1 98.0 98.4 100.0 101.3 102.7 103.5 104.2 104.7 94.0 99.4 103.8

S. Atlantic ..................... 98.6 85.8 95.2 98.4 98.8 103.5 105.4 106.7 108.4 109.4 110.1 110.7 94.5 103.6 109.7

E. S. Central ................ 96.6 79.9 93.6 96.7 97.8 103.8 105.9 107.1 108.4 109.6 110.5 111.2 91.7 103.6 109.9

W. S. Central ............... 100.2 88.9 95.7 97.9 98.8 93.8 95.6 97.2 99.0 100.3 101.1 101.8 95.7 96.3 100.5

Mountain ...................... 102.8 92.2 101.3 104.0 105.2 113.2 115.1 116.2 118.0 119.0 119.7 120.4 100.1 112.4 119.3

Pacific .......................... 96.4 84.0 91.6 93.3 93.4 94.5 96.3 97.4 99.4 100.7 101.5 102.3 91.3 95.4 101.0

Real Personal Income (Billion $2012)

New England ................ 892 978 929 922 1,002 933 922 917 922 930 938 942 930 943 933

Middle Atlantic .............. 2,314 2,522 2,430 2,340 2,574 2,387 2,357 2,335 2,347 2,370 2,391 2,401 2,401 2,413 2,377

E. N. Central ................ 2,457 2,700 2,580 2,535 2,848 2,602 2,557 2,540 2,545 2,570 2,592 2,605 2,568 2,637 2,578

W. N. Central ............... 1,159 1,260 1,180 1,192 1,321 1,231 1,215 1,209 1,206 1,215 1,223 1,227 1,198 1,244 1,218

S. Atlantic ..................... 3,267 3,507 3,411 3,363 3,734 3,455 3,415 3,397 3,408 3,440 3,471 3,491 3,387 3,500 3,453

E. S. Central ................ 911 990 938 933 1,064 973 956 949 947 955 962 966 943 985 957

W. S. Central ............... 2,038 2,202 2,101 2,069 2,325 2,137 2,095 2,102 2,113 2,136 2,158 2,172 2,102 2,165 2,145

Mountain ...................... 1,211 1,317 1,257 1,252 1,398 1,295 1,277 1,270 1,274 1,286 1,296 1,302 1,259 1,310 1,289

Pacific .......................... 2,833 3,036 2,977 2,955 3,196 2,998 2,969 2,949 2,960 2,988 3,014 3,031 2,950 3,028 2,998

Households (Thousands)

New England ................ 5,896 5,855 5,961 5,954 5,955 5,958 5,961 5,975 5,989 6,003 6,016 6,027 5,954 5,975 6,027

Middle Atlantic .............. 16,157 16,042 16,343 16,333 16,341 16,352 16,371 16,417 16,458 16,496 16,528 16,560 16,333 16,417 16,560

E. N. Central ................ 18,873 18,757 19,104 19,077 19,084 19,099 19,123 19,182 19,234 19,272 19,305 19,338 19,077 19,182 19,338

W. N. Central ............... 8,651 8,606 8,770 8,771 8,783 8,796 8,811 8,843 8,871 8,900 8,927 8,948 8,771 8,843 8,948

S. Atlantic ..................... 25,667 25,560 26,072 26,111 26,170 26,234 26,312 26,441 26,558 26,677 26,787 26,886 26,111 26,441 26,886

E. S. Central ................ 7,662 7,625 7,772 7,776 7,787 7,799 7,816 7,847 7,875 7,902 7,928 7,949 7,776 7,847 7,949

W. S. Central ............... 14,881 14,825 15,125 15,153 15,189 15,228 15,277 15,354 15,426 15,497 15,563 15,621 15,153 15,354 15,621

Mountain ...................... 9,461 9,436 9,641 9,670 9,708 9,746 9,789 9,851 9,908 9,962 10,013 10,057 9,670 9,851 10,057

Pacific .......................... 18,795 18,691 19,041 19,043 19,051 19,062 19,087 19,148 19,204 19,251 19,295 19,327 19,043 19,148 19,327

Total Non-farm Employment (Millions)

New England ................ 7.6 6.4 6.8 6.9 7.0 7.1 7.2 7.3 7.4 7.4 7.5 7.5 6.9 7.1 7.5

Middle Atlantic .............. 20.1 16.7 17.9 18.2 18.3 18.5 18.9 19.2 19.4 19.6 19.8 19.9 18.2 18.7 19.7

E. N. Central ................ 22.3 19.3 20.7 20.8 20.9 21.1 21.4 21.7 21.9 22.1 22.2 22.3 20.8 21.3 22.1

W. N. Central ............... 10.8 9.7 10.2 10.2 10.3 10.4 10.5 10.7 10.7 10.8 10.8 10.9 10.2 10.5 10.8

S. Atlantic ..................... 29.3 26.2 27.4 27.8 27.9 28.1 28.6 29.0 29.3 29.5 29.6 29.7 27.7 28.4 29.5

E. S. Central ................ 8.3 7.5 7.9 8.0 8.0 8.1 8.2 8.3 8.3 8.4 8.4 8.4 7.9 8.1 8.4

W. S. Central ............... 17.9 16.2 16.7 17.0 17.1 17.3 17.6 17.7 17.9 18.0 18.1 18.2 17.0 17.4 18.0

Mountain ...................... 11.2 10.0 10.5 10.6 10.7 10.9 11.1 11.2 11.3 11.4 11.5 11.5 10.6 11.0 11.4

Pacific .......................... 24.0 20.9 21.6 21.9 21.9 22.4 22.9 23.3 23.6 23.8 23.9 24.1 22.1 22.7 23.9

Table 9b. U.S. Regional Macroeconomic Data


2020 2021 2022 Year


Forecasts: U.S. macroeconomic forecasts are based on the IHS Markit model of the U.S. Economy.






Historical data: Latest data available from U.S. Department of Commerce, Bureau of Economic Analysis; Federal Reserve System, Statistical release G17.

Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022

Heating Degree Days

New England ................ 2,732 973 114 1,995 3,008 777 128 2,127 3,113 868 140 2,128 5,815 6,040 6,248

Middle Atlantic .............. 2,471 839 85 1,830 2,818 667 79 1,956 2,903 696 89 1,960 5,225 5,520 5,648

E. N. Central ................. 2,785 846 126 2,099 3,086 708 111 2,247 3,160 735 134 2,268 5,857 6,152 6,297

W. N. Central ................ 3,037 800 167 2,314 3,227 719 134 2,451 3,253 706 165 2,472 6,318 6,532 6,596

South Atlantic ............... 1,111 253 17 878 1,347 211 13 957 1,376 195 13 945 2,260 2,528 2,529

E. S. Central ................. 1,479 337 20 1,224 1,790 313 22 1,309 1,805 252 21 1,309 3,059 3,434 3,387

W. S. Central ................ 971 102 8 738 1,301 122 5 797 1,145 85 4 797 1,819 2,226 2,031

Mountain ....................... 2,220 677 128 1,781 2,303 665 126 1,839 2,226 696 144 1,827 4,805 4,934 4,892

Pacific ........................... 1,538 528 65 1,084 1,558 487 85 1,235 1,547 575 87 1,203 3,215 3,364 3,412

U.S. Average ............ 1,881 544 71 1,422 2,107 473 68 1,530 2,113 488 77 1,525 3,918 4,178 4,202

Heating Degree Days, Prior 10-year Average

New England ................ 3,152 822 105 2,127 3,133 856 107 2,099 3,100 852 112 2,123 6,207 6,195 6,187

Middle Atlantic .............. 2,948 644 69 1,944 2,913 678 72 1,911 2,887 685 74 1,931 5,606 5,573 5,576

E. N. Central ................. 3,198 698 102 2,197 3,157 731 105 2,170 3,133 728 101 2,198 6,195 6,162 6,160

W. N. Central ................ 3,288 703 132 2,380 3,248 728 133 2,368 3,219 726 130 2,399 6,502 6,477 6,474

South Atlantic ............... 1,461 169 10 953 1,395 181 11 916 1,380 187 11 921 2,593 2,503 2,499

E. S. Central ................. 1,849 214 15 1,277 1,771 231 16 1,249 1,763 243 15 1,255 3,356 3,267 3,276

W. S. Central ................ 1,199 83 3 794 1,140 86 3 786 1,145 93 3 784 2,078 2,015 2,026

Mountain ....................... 2,198 721 136 1,850 2,188 704 135 1,850 2,180 686 134 1,838 4,905 4,877 4,838

Pacific ........................... 1,456 580 85 1,162 1,462 553 81 1,147 1,454 523 80 1,139 3,283 3,242 3,196

U.S. Average ............ 2,153 473 64 1,512 2,113 483 65 1,487 2,096 479 64 1,495 4,202 4,148 4,134

Cooling Degree Days

New England ................ 0 103 544 0 0 149 430 2 0 81 397 2 647 581 481

Middle Atlantic .............. 0 155 682 4 0 184 603 5 0 149 526 5 841 792 680

E. N. Central ................. 2 218 605 2 2 253 587 7 0 213 520 6 827 849 739

W. N. Central ................ 6 295 662 3 8 312 700 10 3 263 657 9 966 1,030 932

South Atlantic ............... 192 616 1,228 298 150 622 1,161 229 131 649 1,160 245 2,334 2,163 2,186

E. S. Central ................. 74 426 1,062 80 41 435 1,020 62 29 505 1,036 64 1,642 1,557 1,634

W. S. Central ................ 173 838 1,503 210 89 766 1,425 195 90 851 1,497 200 2,723 2,476 2,639

Mountain ....................... 10 462 1,076 116 10 528 930 76 18 424 931 77 1,664 1,544 1,450

Pacific ........................... 25 195 716 125 24 256 684 60 27 171 593 60 1,061 1,024 852

U.S. Average ............ 69 392 931 120 49 413 875 92 45 396 848 96 1,513 1,429 1,384

Cooling Degree Days, Prior 10-year Average

New England ................ 0 83 471 1 0 81 474 1 0 88 469 1 554 556 558

Middle Atlantic .............. 0 170 609 6 0 163 610 6 0 162 606 7 786 779 774

E. N. Central ................. 3 240 579 8 3 234 572 7 3 238 567 7 829 816 815

W. N. Central ................ 7 296 696 11 7 294 686 10 7 299 677 10 1,010 997 993

South Atlantic ............... 127 695 1,201 247 142 679 1,194 260 146 668 1,188 263 2,270 2,276 2,266

E. S. Central ................. 36 557 1,082 72 42 532 1,065 74 44 518 1,058 77 1,747 1,714 1,697

W. S. Central ................ 100 892 1,576 207 114 880 1,567 210 113 852 1,531 211 2,775 2,771 2,708

Mountain ....................... 24 430 934 80 24 441 949 85 23 458 942 85 1,468 1,499 1,508

Pacific ........................... 31 185 624 78 31 193 647 86 31 208 662 85 919 958 987

U.S. Average ............ 47 419 891 99 52 413 892 104 53 412 886 105 1,455 1,461 1,457

Table 9c. U.S. Regional Weather Data


2020 2021 2022 Year

Regions refer to U.S. Census divisions. See "Census division" in EIA’s Energy Glossary (http://www.eia.gov/tools/glossary/) for a list of states in each region.

Historical data: Latest data available from U.S. Department of Commerce, National Oceanic and Atmospheric Association (NOAA).

Forecasts: Based on forecasts by the NOAA Climate Prediction Center (http://www.cpc.ncep.noaa.gov/pacdir/DDdir/NHOME3.shtml).




Regional degree days for each period are calculated by EIA as contemporaneous period population-weighted averages of state degree day data published by the National

Oceanic and Atmospheric Administration (NOAA).See Change in Regional and U.S. Degree-Day Calculations (http://www.eia.gov/forecasts/steo/special/pdf/2012_sp_04.pdf) for more information.


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